CN114810047A - Method, device and equipment for determining borehole trajectory in oil reservoir stratum and storage medium - Google Patents

Method, device and equipment for determining borehole trajectory in oil reservoir stratum and storage medium Download PDF

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Publication number
CN114810047A
CN114810047A CN202110088538.2A CN202110088538A CN114810047A CN 114810047 A CN114810047 A CN 114810047A CN 202110088538 A CN202110088538 A CN 202110088538A CN 114810047 A CN114810047 A CN 114810047A
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target
reservoir
target reservoir
model
determining
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金涛
金戈
杨国红
韦腾强
刘敏
赵正望
白蓉
李秀清
吴长江
李楠
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Petrochina Co Ltd
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Petrochina Co Ltd
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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/02—Determining slope or direction
    • E21B47/022—Determining slope or direction of the borehole, e.g. using geomagnetism

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  • Engineering & Computer Science (AREA)
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  • Mining & Mineral Resources (AREA)
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  • Environmental & Geological Engineering (AREA)
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  • Geochemistry & Mineralogy (AREA)
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Abstract

The application relates to a method, a device, equipment and a storage medium for determining a borehole trajectory in an oil reservoir, and relates to the field of oil reservoir exploration. The method comprises the following steps: acquiring stratum characteristic parameters corresponding to a target reservoir, wherein the stratum characteristic parameters at least comprise the thickness of a hard stratum contained in the target reservoir; determining a target reservoir type corresponding to a target reservoir according to the stratum characteristic parameters, wherein the reservoir type indicates the distribution characteristics of the hard stratum in the target reservoir; and determining a target borehole trajectory corresponding to the target reservoir according to the type of the target reservoir, wherein the target borehole trajectory is used for indicating the deployment position of the borehole in the target reservoir. The method can deploy proper well positions for the reservoir stratum with different hard stratum distribution characteristics, avoid the collapse phenomenon in the exploration process, reduce the cost in the reservoir stratum exploration process and further improve the success rate in the reservoir stratum exploration process.

Description

Method, device and equipment for determining borehole trajectory in oil reservoir stratum and storage medium
Technical Field
The application relates to the field of oil reservoir exploration, in particular to a method, a device, equipment and a storage medium for determining a borehole trajectory in an oil reservoir.
Background
With the development of the drilling technology, particularly, the technology of horizontal well and volume fracturing is applied to drilling, and the drilling of unconventional oil and gas such as shale oil and gas enters a brisk development stage.
The shale oil and gas reservoir is mainly stored in a soft stratum, the soft stratum refers to a stratum with loose and soft structures such as a mud layer and a sand layer, and due to the characteristics of the soft stratum, the shale oil and gas reservoir is easy to collapse in the drilling process of the soft stratum.
In the related technology, modes such as a horizontal well and a highly deviated well are mostly adopted for drilling soft formations such as shale oil gas, wherein the horizontal well is applied to the drilling process of the soft formations, the oil gas yield can be effectively improved as the horizontal well drills along a high-quality reservoir, but due to the characteristics of the soft formations, the horizontal well is easy to collapse in the drilling process, so that the drilling cost is high; if a highly deviated well is used for drilling a soft stratum, the oil and gas yield is lower.
Disclosure of Invention
The embodiment of the application provides a method, a device, equipment and a storage medium for determining a borehole trajectory in an oil reservoir, and can reduce the cost in the oil reservoir exploration process. The technical scheme is as follows:
in one aspect, a method for determining a borehole trajectory in a reservoir is provided, the method comprising:
obtaining stratum characteristic parameters corresponding to a target reservoir, wherein the stratum characteristic parameters at least comprise the thickness of a hard stratum contained in the target reservoir;
determining a target reservoir type corresponding to the target reservoir according to the stratum characteristic parameters, wherein the reservoir type indicates the distribution characteristics of the hard stratum in the target reservoir;
and determining a target borehole trajectory corresponding to the target reservoir according to the type of the target reservoir, wherein the target borehole trajectory is used for indicating the deployment position of the borehole in the target reservoir, and the distribution characteristics of different hard formations correspond to different target borehole trajectories.
In another aspect, an apparatus for determining a borehole trajectory in a reservoir is provided, the apparatus comprising:
the system comprises an acquisition module, a storage module and a processing module, wherein the acquisition module is used for acquiring stratum characteristic parameters corresponding to a target reservoir, and the stratum characteristic parameters at least comprise the thickness of a hard stratum contained in the target reservoir;
the first determination module is used for determining a target reservoir type corresponding to the target reservoir according to the stratum characteristic parameters, wherein the reservoir type indicates the distribution characteristics of the hard stratum in the target reservoir;
and the second determination module is used for determining a target borehole trajectory corresponding to the target reservoir according to the type of the target reservoir, wherein the target borehole trajectory is used for indicating the deployment position of the borehole in the target reservoir, and the distribution characteristics of different hard formations correspond to different target borehole trajectories.
In another aspect, a computer apparatus is provided, which includes a processor and a memory, the memory having at least one instruction stored therein, the instruction being loaded and executed by the processor to implement the method for determining a well bore trajectory in a reservoir as described in the above aspects.
In another aspect, a computer-readable storage medium is provided, having stored therein at least one instruction, which is loaded and executed by a processor to implement the method for determining a well bore trajectory in a reservoir as described in the above aspects.
In another aspect, according to an aspect of the present application, there is provided a computer program product or a computer program comprising computer instructions stored in a computer readable storage medium. A processor of the computer device reads the computer instructions from the computer readable storage medium, and the processor executes the computer instructions to cause the computer device to perform the method for determining a well bore trajectory in a reservoir provided in the various alternative implementations of the above aspects.
The beneficial effects brought by the technical scheme provided by the embodiment of the application at least comprise:
the method comprises the steps of determining the type of a reservoir corresponding to the reservoir by analyzing the distribution characteristics of the hard formation in the reservoir, so that in the actual exploration process, the well track suitable for the reservoir can be determined according to the type of the reservoir, appropriate well positions can be deployed for the reservoirs with different hard formation distribution characteristics, the collapse phenomenon in the exploration process is avoided, the cost in the reservoir exploration process is reduced, and the success rate in the reservoir exploration process is improved.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present application, the drawings needed to be used in the description of the embodiments are briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present application, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.
FIG. 1 illustrates a flow chart of a method for determining a trajectory of a wellbore in a reservoir provided by an exemplary embodiment of the present application;
FIG. 2 illustrates a flow chart of a method for determining a trajectory of a wellbore in a reservoir provided by another exemplary embodiment of the present application;
FIG. 3 illustrates a schematic view of a reservoir corresponding to a barrier-free type according to an exemplary embodiment of the present application;
FIG. 4 illustrates a schematic of a reservoir corresponding to a thin-wall type shown in an exemplary embodiment of the present application;
FIG. 5 illustrates a schematic representation of a reservoir corresponding to a thick spacer type as shown in an exemplary embodiment of the present application;
FIG. 6 illustrates a schematic view of a basin model shown in an exemplary embodiment of the present application;
FIG. 7 illustrates a schematic diagram of a horizontal model shown in an exemplary embodiment of the present application;
FIG. 8 illustrates a schematic diagram of a wave model shown in an exemplary embodiment of the present application;
FIG. 9 illustrates a block diagram of an apparatus for determining a borehole trajectory in a reservoir provided by an exemplary embodiment of the present application;
fig. 10 shows a schematic structural diagram of a computer device provided in an exemplary embodiment of the present application.
Detailed Description
Reference will now be made in detail to the exemplary embodiments, examples of which are illustrated in the accompanying drawings. When the following description refers to the accompanying drawings, like numbers in different drawings represent the same or similar elements unless otherwise indicated. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with the present application. Rather, they are merely examples of apparatus and methods consistent with certain aspects of the present application, as detailed in the appended claims.
It should be noted that the method for determining a borehole trajectory in a reservoir provided in each embodiment of the present application is applied to a reservoir whose formation characteristics are soft formations, the soft formations may be mixed with hard formations, and the borehole trajectory to which the reservoir is applied is determined by analyzing distribution characteristics of the hard formations in the soft formations, for example, the thickness of the hard formations contained in the soft formations.
Referring to fig. 1, a flow chart of a method for determining a trajectory of a wellbore in a reservoir provided by an exemplary embodiment of the present application is shown. The embodiment of the application is described by taking the method as an example of being applied to computer equipment, and the method comprises the following steps:
step 101, stratum characteristic parameters corresponding to a target reservoir are obtained, wherein the stratum characteristic parameters at least comprise the thickness of a hard stratum contained in the target reservoir.
The method for determining the borehole trajectory is provided for exploration of oil and gas reservoirs such as shale oil and gas which are contained in a soft stratum, correspondingly, the target reservoir in the embodiment of the application is the soft stratum, and optionally, due to the complexity of geological conditions, a part of hard stratum may be mixed in the soft stratum. Wherein, the soft stratum is composed of rocks with lower hardness, is easy to collapse in drilling and mainly comprises shale, mudstone and the like; the hard stratum is composed of rock with high hardness, is not easy to collapse in drilling and mainly comprises sandstone, carbonate rock and the like.
The formation characteristic parameters may include whether the target reservoir contains a hard formation layer and the thickness of the contained hard formation layer. Optionally, the formation characteristic parameter may further include a thickness of the target reservoir. Optionally, the formation characteristic parameter may further include a formation pressure corresponding to the target reservoir. The embodiments of the present application do not limit specific formation characteristic parameters.
In a possible implementation manner, when a drilling process is performed on a target reservoir, formation characteristic parameters corresponding to the target reservoir need to be measured and acquired first, in this embodiment, thicknesses of hard formations distributed in the target reservoir are mainly measured so as to be used for determining a reservoir type to which the target reservoir belongs.
And 102, determining a target reservoir type corresponding to the target reservoir according to the stratum characteristic parameters, wherein the reservoir type indicates the distribution characteristics of the hard stratum in the target reservoir.
The reservoir type refers to the distribution characteristics of hard formations in a target reservoir, for example, the target reservoir is completely a soft formation and has no hard formations; or only a small portion of the hard formation; or a hard stratum with a certain thickness is uniformly distributed in the target reservoir; or thicker hard formations distributed in the target reservoir.
In one 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.
The target reservoir type may be a non-interlayer (including no hard formation layer, or including a hard formation layer but having an extremely thin thickness), a thick interlayer (including a hard formation layer and having a thick thickness), a thin interlayer (including a hard formation layer and having a thin thickness), or may be divided more finely according to the thickness of the hard formation layer, and the target reservoir type is not limited in the embodiments of the present application.
And 103, determining a target borehole trajectory corresponding to the target reservoir according to the type of the target reservoir, wherein the target borehole trajectory is used for indicating the deployment position of the borehole in the target reservoir.
In the related art, for the exploration process of a soft stratum, a horizontal well is usually adopted, but due to the characteristics of the soft stratum, if the horizontal well is used, collapse is easy to occur in the soft stratum drilling process, and in order to avoid the collapse, drilling cost is usually required to be greatly improved, in the embodiment of the application, in order to reduce the drilling cost of the soft stratum and solve the problem of easy collapse in the soft stratum drilling process, a target borehole trajectory corresponding to a target reservoir is determined according to the distribution characteristics by analyzing the distribution characteristics of a hard stratum in the target reservoir, so that the borehole trajectory can accord with the reservoir type of the target reservoir.
Wherein 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 suitable for the target reservoir is determined by the distribution characteristics of the hard formation in the soft formation.
In an illustrative example, if the target reservoir is of the barrier-free type, i.e., the target reservoir contains no hard formation or contains few hard formations, a wellbore trajectory having a cross section in the form of a water trough may be used, the wellbore trajectory having a descending section, a horizontal section, and an ascending section, wherein the descending section and the ascending section have a slope to prevent collapse, and the horizontal section is located in the hard formation adjacent to the target reservoir to further prevent collapse.
In summary, in the embodiment of the application, the reservoir type corresponding to the reservoir is determined by analyzing the distribution characteristics of the hard formation in the reservoir, so that in the actual exploration process, the well track suitable for the reservoir can be determined according to the reservoir type, a proper well position can be deployed for the reservoir with different hard formation distribution characteristics, the collapse phenomenon in the exploration process is avoided, the cost in the reservoir exploration process is reduced, and the success rate in the reservoir exploration process is improved.
According to the distribution characteristics of the hard stratum in the soft stratum, the soft stratum is divided into three types, namely a non-interlayer type, a thick interlayer type, a thin interlayer type and the like; correspondingly, aiming at the three types, the applicable well track models are respectively designed, wherein the non-interlayer type is applicable to the water tank model, and the thick interlayer type is applicable to the horizontal model; the thin-layer type is suitable for the wave model, and the following examples focus on several soft-formation types and the well trajectory models to which they are suitable.
In one illustrative example, as shown in FIG. 2, a flow chart of a method for determining a borehole trajectory in a reservoir provided by another illustrative embodiment of the present application is shown. The embodiment of the present application is described by taking an example that the method is applied to a computer device, and the method includes:
step 201, obtaining stratum characteristic parameters corresponding to a target reservoir, wherein the stratum characteristic parameters at least comprise the thickness of a hard stratum contained in the target reservoir.
The implementation manner of step 201 may refer to the above embodiments, which are not described herein.
Step 202, if the thickness of the hard formation layer contained in the target reservoir is smaller than a first thickness threshold value, determining the type without the interlayer as the target reservoir type corresponding to the target reservoir.
In a possible implementation manner, the type of the target reservoir is divided according to the thickness of a hard formation layer contained in the target reservoir, where the first thickness threshold is determined by an engineer according to the actual condition of the target reservoir, for example, the first thickness threshold is 0.2m, when the thicknesses of the hard formation layers included in the target reservoir are all less than 0.2m, it indicates that all the target reservoir are soft formation layers or a small part of hard formation layers are included in the soft formation layers, and the thicknesses of the hard formation layers are negligible, then the corresponding reservoir type of the target reservoir is a non-interlayer type.
As shown in fig. 3, a schematic view of a reservoir corresponding to a barrier-free type according to an exemplary embodiment of the present application is shown. Wherein, the target reservoirs are soft formations and hard formations do not exist.
In an illustrative example, if the target reservoir does not contain hard formations in the measurements, determining that the target reservoir is of a barrier-free type; if the first thickness threshold value is 0.2m, the target reservoir stratum obtained through measurement comprises a hard stratum, the thickness of the hard stratum is 0.1m, and correspondingly, the target reservoir stratum is determined to be of a non-interlayer type.
In step 203, if the thickness of the hard formation layer included in the target reservoir is greater than the first thickness threshold and less than the second thickness threshold, the thin-layer type is determined as the target reservoir type corresponding to the target reservoir.
In one possible embodiment, if the target reservoir is interspersed with hard formations and the thickness of the hard formations is between the first thickness threshold and the second thickness threshold, i.e. the soft formations are interspersed with thinner hard formations, such target reservoir is correspondingly determined to be of the thin-interval type.
The second thickness threshold may be set by an engineer, for example, the second thickness threshold is 1 m.
As shown in fig. 4, a schematic of a reservoir corresponding to a thin-walled type is shown in an exemplary embodiment of the present application. A soft formation (target reservoir) is interspersed with a thin hard formation.
In an exemplary example, if the first thickness threshold is 0.2m, the second thickness threshold is 1m, 3 hard formation layers are distributed in the target reservoir, the thickness of the first hard formation layer is 0.3m, the thickness of the second hard formation layer is 0.4m, and the thickness of the third hard formation layer is 0.7m, it can be seen that the thickness of each hard formation layer in the target reservoir is located between the first thickness threshold and the second thickness threshold, and correspondingly, the reservoir type corresponding to the target reservoir is determined to be a thin-layer type.
And 204, if the thickness of the hard formation layer contained in the target reservoir is greater than the second thickness threshold value, determining the type of the thick interlayer as the type of the target reservoir corresponding to the target reservoir.
In one possible embodiment, if at least one hard formation layer in the target reservoir has a greater thickness than the second thickness threshold, the corresponding target reservoir is determined to be of the thick spacer type.
In an exemplary example, if the second thickness threshold is 1m, the target reservoir includes 3 hard formation layers, the thickness of the first hard formation layer is 0.5m, the thickness of the second hard formation layer is 2m, and the thickness of the third hard formation layer is 0.2m, it is seen that the thickness of the second hard formation layer is greater than the second thickness threshold, it is determined that the thickness of one hard formation layer in the target reservoir is greater than the second thickness threshold, and the corresponding target reservoir is determined to belong to the thick spacer type.
As shown in fig. 5, a schematic of a reservoir corresponding to the thick spacer type shown in an exemplary embodiment of the present application is shown. Wherein the soft formation (target reservoir) is interspersed with hard formations having a thickness H, wherein H is greater than the second thickness threshold.
Step 205, determining a target borehole trajectory model corresponding to the target reservoir according to the type of the target reservoir, wherein different reservoir types correspond to different borehole trajectory models, and the target borehole trajectory model is a trajectory form corresponding to the target borehole trajectory in the target reservoir.
In the embodiment of the application, different borehole trajectory models are designed according to different reservoir types, and the borehole trajectory models are used for indicating the trajectory forms corresponding to the borehole trajectories in the reservoir.
The well track model comprises three types, namely a water tank model, a horizontal model and a wave model. The basin model indicates the morphology of the well trajectory in the reservoir as a cross section of the basin; the horizontal model indicates a morphological approximation level of the wellbore trajectory in the reservoir; the wave model indicates that the morphology of the wellbore trajectory in the reservoir resembles a wave.
Wherein the process of determining the target wellbore trajectory model from the target reservoir type may comprise the steps of:
if the target reservoir type is a non-interlayer type, determining the water tank model as a target well track model corresponding to the target reservoir.
The water tank model comprises a first descending section, a first horizontal section and a first ascending section, wherein the first descending section is connected with the first horizontal section, and the first horizontal section is connected with the first ascending section. The ascending section and the descending section have certain inclination, the inclination can prevent the collapse phenomenon in the drilling process, and the oil gas in the soft stratum can be contacted in a large area, so that the oil gas exploitation is facilitated, and the oil gas recovery rate is improved; the bottom horizontal section penetrates through the hard stratum (the hard stratum is the bottom layer adjacent to the target reservoir stratum) to further prevent collapse, and the hard stratum can be penetrated after the bottom horizontal section is perforated to fracture oil gas stored in the soft stratum, so that oil gas exploitation is facilitated, and the oil gas recovery ratio is improved.
For the target reservoir stratum of the non-interlayer type, most of the reservoir stratum is a soft stratum, and if a horizontal well is adopted in the drilling process, collapse is easy to occur, so that in order to prevent collapse, based on the characteristics of the water tank model, the descending section and the ascending section in the water tank model both have certain slopes, and the horizontal section is also positioned in a hard stratum, collapse can be prevented, and for the target reservoir stratum of the non-interlayer type, the water tank model is determined to be the target borehole trajectory model suitable for the target reservoir stratum.
As shown in fig. 6, which illustrates a schematic view of a basin module shown in an exemplary embodiment of the present application. The thickness of the target reservoir is H, the target reservoir is of a non-interlayer type, namely, no hard formation exists in the thickness of H, the target reservoir is adjacent to the hard formation, the water tank model 601 comprises a descending section 602, a horizontal section 603 and an ascending section 604, the descending section 602 and the ascending section 604 are located in a soft formation, and the horizontal section 603 is located in the hard formation; and the angle between the down leg 602 and the plumb line is the angle θ of the down leg 602 1 The angle between the up leg 604 and the vertical is the angle θ of the up leg 604 2 (ii) a The horizontal segment 603 has a length L 2 The length of the water tank model 601 in the horizontal direction is L 1 。
Optionally, the ascending section of the well track in the water tank model is sealed and pressurized, and the formation pressure corresponding to the target reservoir can be improved, so that the oil gas accumulated in the low-pressure layer of the soft formation is promoted to move to the descending section and the horizontal section, the oil gas exploitation is facilitated, and the oil gas recovery rate is improved.
Optionally, the water tank model is provided with a descending section and an ascending section, and correspondingly, the descending section of the water tank model can be sealed and pressurized, and the formation pressure corresponding to the target reservoir can also be improved, so that the oil gas accumulated in the low-pressure layer of the soft formation is promoted to move to the ascending section and the horizontal section, and the aim of improving the oil gas recovery ratio can also be achieved.
And secondly, if the target reservoir type is the thick interlayer type, determining the horizontal model as a target well track model corresponding to the target reservoir.
The horizontal model comprises a second descending section and a second horizontal section, the second descending section is connected with the second horizontal section, the second descending section is located in the soft stratum, the second horizontal section is located in the hard stratum, and the second descending section has a certain inclination so that collapse can be prevented; moreover, because the second horizontal section is positioned in a thicker hard stratum, the collapse can be further prevented, and the drilling tool is suitable for geological steering and drilling.
For a reservoir with a thick interlayer type, because a thick hard stratum exists in the reservoir and the hard stratum can divide the reservoir into unconnected soft strata, in order to prevent the reservoir from collapsing in the drilling process of the soft stratum and fully improve the recovery ratio of oil and gas in the soft stratum, in one possible implementation mode, a horizontal model is determined as a target borehole trajectory model applicable to the reservoir with the thick interlayer type.
As shown in fig. 7, which shows a schematic diagram of a horizontal model shown in an exemplary embodiment of the present application. The thickness of a target reservoir is H, a thicker hard stratum is filled in the target reservoir, the hard stratum divides the target reservoir into two discontinuous soft strata, the target reservoir is suitable for a horizontal model, the horizontal model 701 comprises a descending section 702 and a horizontal section 703, the descending section 702 is located in the soft stratum, the horizontal section 703 is located in the hard stratum, an included angle between the descending section 702 and a plumb line is a well inclination angle theta corresponding to the descending section 702, and the length of the horizontal section on the ground of the horizontal model 701 is L.
As can be seen from FIG. 7, since the hard formation is located in the middle of the soft formation, the hard formation can be perforated after the perforation is performed in the horizontal section indicated by the horizontal model, so that the oil gas accumulated in the upper soft formation and the lower soft formation of the hard formation can be contacted in a large area, the oil gas exploitation is facilitated, and the oil gas recovery ratio is improved.
And thirdly, if the target reservoir type is the thin-layer type, determining the wave model as a target borehole trajectory model corresponding to the target reservoir.
The wave-shaped model comprises at least one third downlink section and at least one second uplink section, and the third downlink section is connected with the second uplink section; and the descending section and the ascending section have certain inclination, so that the collapse can be prevented.
Aiming at a reservoir with a thin-partition type, because a plurality of thin hard strata are distributed in the reservoir and the hard strata divide the reservoir into a plurality of sections of unconnected soft strata, in order to avoid the collapse phenomenon easily caused by drilling in the soft strata, and simultaneously, oil and gas stored in the divided soft strata can be communicated, in a possible implementation mode, a wave model is determined as a target borehole trajectory model corresponding to the thin-partition type.
As shown in fig. 8, which illustrates a schematic view of a wave model shown in an exemplary embodiment of the present application. The target reservoir with the thickness of H comprises a plurality of hard strata, the hard strata divide oil gas contained in the soft strata into a plurality of sets of oil gas flowing units which are not communicated with each other, the target reservoir is suitable for a wave model 801, the wave model 801 comprises a plurality of groups of descending sections 802 and ascending sections 803, the descending sections 802 and the ascending sections 803 can penetrate through the hard strata and the soft strata, and an included angle between the descending sections 802 and a plumb line is theta 1 The angle between the ascending section 803 and the vertical line is theta 2 。
It can be known from fig. 8 that the wave model mainly comprises a plurality of sets of descending sections and ascending sections, because of the existence of a plurality of hard strata in the reservoir, the oil gas in the soft strata is divided into a plurality of sets of oil gas flowing units which are not communicated, and the wave model is adopted, on one hand, the inclination of the well track of the descending sections and the ascending sections can prevent collapse in the drilling process, and can drill through the interlayer (namely the hard strata) to communicate the oil gas in the divided soft strata, and the oil gas in the soft strata can be contacted in a large area, thereby being beneficial to oil gas exploitation and further improving the oil gas recovery ratio.
In summary, the wellbore trajectory models suitable for the reservoir design in this embodiment are designed for different types of reservoirs, wherein the non-spacer type is suitable for the water tank model, the thin-spacer type is suitable for the wave model, and the thick-spacer type is suitable for the horizontal model.
Optionally, based on the advantages of different wellbore trajectory models, the wellbore trajectory model may also be applied to other types of reservoirs, for example, because the water tank model may increase the formation pressure by sealing and pressurizing the descending section in the application process, and may push the oil gas accumulated in the low-pressure layer of the soft formation to move to the descending section and the horizontal section, which is beneficial to oil gas exploitation, and correspondingly, the low-pressure layer may also be applied to the water tank model. The engineer may select an appropriate borehole trajectory model based on the reservoir characteristics and the desired purpose, and is not limited to the applicable relationships shown in the above embodiments.
In another possible embodiment, when it is determined that the formation pressure of the soft formation is lower than the preset pressure threshold and the hard formation exceeding the first thickness threshold does not exist in the soft formation, the water tank model is also applicable to the low-pressure layer. Wherein the preset pressure threshold may be 0.9Mpa/100 m.
And step 206, determining a target borehole trajectory corresponding to the target reservoir according to the target borehole trajectory model and the stratum characteristic parameters.
In a possible implementation manner, after a target wellbore trajectory model applicable to a target reservoir is determined, if the target wellbore trajectory model needs to be applied to the target reservoir, actual parameters of each part of the target wellbore trajectory model are calculated according to actual formation characteristic parameters corresponding to the target reservoir correspondingly, so that a target wellbore trajectory corresponding to the target reservoir is obtained.
In one illustrative example, a method for determining a target borehole trajectory based on a model of the target borehole trajectory and formation characteristic parameters may include the steps of:
if the target borehole trajectory model is a water tank model, calculating the length of a first horizontal section of the target borehole trajectory corresponding to the target reservoir according to the thickness of the target reservoir and the first control radius, wherein the length of the first horizontal section is the actual length of the first horizontal section in the water tank model.
Aiming at the situation that the target reservoir stratum is of a non-interlayer type and the target borehole trajectory model is a water tank model, in the practical application process, the length of a horizontal section, the inclination angle of a descending section and the inclination angle of an ascending section in the water tank model in the practical application situation need to be determined in advance, so that the practical borehole trajectory corresponding to the target reservoir stratum can be determined according to the parameters.
Because the descending section and the ascending section in the water tank model are located in the soft stratum, in order to avoid collapse in the drilling process, the inclination angles corresponding to the descending section and the ascending section need to meet the condition of being not easy to collapse, for example, the inclination angle of the descending section can be 45 degrees, and the inclination angle of the ascending section can be 135 degrees. The embodiment of the application does not limit the specific numerical values of the inclination angles corresponding to the descending section and the ascending section respectively, and can perform self-adaptive adjustment according to the actual reservoir.
As can be seen from FIG. 6, two horizontal lengths are required to be determined in the water tank model, one of which is the actual length L of the horizontal segment arranged in the hard formation 1 Secondly, the length L of the water tank model at the upper part of the soft stratum 2 In practical application, L 1 And L 2 Is related to the thickness of the target reservoir and the control radius, and therefore, in a possible embodiment, the first horizontal segment length of the target wellbore trajectory corresponding to the target reservoir is calculated by measuring the thickness of the target reservoir and the first control radius applicable to the target reservoir.
The control radius is related to the permeability of the target reservoir, the higher the permeability corresponding to the target reservoir is, the larger the control radius corresponding to the target reservoir is, and conversely, the lower the permeability corresponding to the target reservoir is, the smaller the control radius corresponding to the target reservoir is. The control radius may take the value of 500 m.
In an illustrative example, the actual parametric relationship for the basin model may be as follows, for example, with the following rows at a 45 degree angle and the upper row at a 135 degree angle:
L 1 ＝2×R 1 +H
L 2 ＝2×R 1 -H
θ 1 ＝45°
θ 2 ＝135°
wherein L is 1 Represents the upper length of the water tank model in the reservoir (i.e. the length of all well tracks in the reservoir in the horizontal direction), L 2 Representing the lower length of the basin model in the reservoir (i.e., the actual length of the horizontal section in the basin model), R 1 Representing the average radius of hydrocarbon flow in the horizontal direction from the soft formation into the wellbore (i.e., the first control radius), H represents the soft formation thickness (i.e., the thickness of the target reservoir), θ 1 The included angle between the well track and the vertical straight line (namely the well inclination angle corresponding to the descending section in the water tank model) is shown when the water enters the lower part of the soft stratum from the upper part of the soft stratum; theta 2 And the included angle between the well track and the vertical straight line (namely the well inclination angle corresponding to the upper ascending section in the water tank model) when the well enters the upper part of the soft stratum from the lower part of the soft stratum is shown.
Optionally, if the target wellbore trajectory model is a water tank model, the corresponding formation characteristic parameters to be measured further include: the thickness of the target reservoir and the corresponding first control radius of the target reservoir.
And if the target borehole trajectory model is a horizontal model, calculating the length of a second horizontal section of the target borehole trajectory corresponding to the target reservoir according to the second control radius, wherein the length of the second horizontal section is the actual length of the second horizontal section in the horizontal model.
In an actual application scenario, the length of a horizontal section and the inclination angle of a descending section in the horizontal model in actual application need to be predetermined so as to determine the actual borehole trajectory corresponding to the target reservoir according to the parameters.
Because the descending section in the horizontal model is located in the soft stratum, in order to avoid collapse during drilling, the inclination angle of the descending section needs to meet the condition of difficult collapse, and the inclination angle of the descending section should be an acute angle, for example, the inclination angle of the descending section is 45 degrees. And the engineering personnel can carry out self-adaptive adjustment on the inclination angle of the descending section according to the actual reservoir.
As can be seen from fig. 7, 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 practical application, that is, the length of the second horizontal segment corresponding to the target wellbore trajectory, and in practical application, the actual length of L is related to the control radius corresponding to the target reservoir.
The second control radius is determined by the permeability corresponding to the target reservoir, the higher the permeability corresponding to the target reservoir is, the larger the corresponding second control radius is, and otherwise, the smaller the second control radius is.
In an exemplary example, the relationship between the various parameters in the horizontal model may be expressed as:
L 3 ＝4×R 2
45°≤θ 3 ＜90°
wherein L is 3 The horizontal segment length (i.e., the length of the horizontal segment in the water tank model that is located in the hard formation), R, representing the borehole trajectory in the reservoir 2 Representing the average radius of the flow of hydrocarbons in the horizontal direction from the soft formation into the wellbore (i.e., the second control radius), θ 3 And the included angle between the well track in the soft stratum and the vertical line (namely the well inclination angle corresponding to the descending section) is shown.
And if the target well track model is a wave model, calculating a third horizontal length of the target well track corresponding to the target reservoir according to a third control radius, and calculating a well inclination angle of the target well track corresponding to the target reservoir according to the third control radius and the thickness of the target reservoir, wherein the well inclination angle comprises a well inclination angle of a third descending section and a well inclination angle of a second ascending section in the wave model.
In the actual application process, for a scenario that the target reservoir is of a thin-layer type and the target wellbore trajectory model is a wave model, the length of the wave model in the horizontal direction and the inclination angles of each group of descending sections and ascending sections need to be predetermined, so that the actual wellbore trajectory corresponding to the target reservoir is determined according to the parameters.
Because the descending section and the ascending section in the wave model penetrate through the soft stratum, in order to avoid collapse in the drilling process, the inclination angles corresponding to the descending section and the ascending section are set to meet the condition of no collapse, for example, the inclination angle of the descending section can be 50 degrees, the inclination angle of the ascending section can be 130 degrees, the specific numerical value of the inclination angle is not limited in the embodiment, and engineering personnel can adaptively adjust the inclination angle according to actual requirements.
In one possible embodiment, the third horizontal length of the wellbore trajectory in the target reservoir in the horizontal direction, i.e., L in fig. 8, is determined according to the third control radius by obtaining a third control radius applicable to the target reservoir, and the well deviation angles in the downward section and the upward section in the target wellbore trajectory (i.e., θ in fig. 8) are calculated according to the thickness of the target reservoir and the third control radius 1 And theta 2 )。
In an exemplary example, the relationship between the various parameters in the wave model may be expressed as:
L 4 ＝4×R 3
θ 4 ＝arctan(R 3 /H)
θ 5 ＝180°-arctan(R 3 /H)
wherein L is 4 Representing a third horizontal length, R, in the horizontal direction of the reservoir 3 Representing the average radius of hydrocarbon flow in the horizontal direction from the soft formation into the wellbore (i.e., the third control radius), H representing the thickness of the target reservoir, θ 4 The included angle between the well track and the vertical straight line (namely the well inclination angle corresponding to the descending section in the wave model) theta is expressed when the well enters the lower part of the target reservoir from the upper part of the target reservoir 5 The included angle between the well track and the vertical straight line (namely the well inclination angle corresponding to the ascending section in the wave model) is shown when the well enters the upper part of the target reservoir from the lower part of the target reservoir; arctan (x) represents the arctangent function.
In summary, in a possible implementation manner, after the target wellbore trajectory model corresponding to the target reservoir is determined, parameters of each target wellbore trajectory model in the actual application process, such as the inclination angle and the horizontal section length, may be calculated according to the above formulas for calculating the wellbore trajectory, and the actual wellbore trajectory in the target reservoir is determined according to the calculated parameters.
In the embodiment, the well track models suitable for the reservoirs of different types are specially arranged, so that parameters of all parts of the well track in the practical application process can be determined according to the well track models, the basis is provided for well position deployment, the success rate of the later exploration process is improved, and the oil and gas recovery rate is further improved.
In an exemplary example, the geological features of the target reservoir are respectively obtained through geological evaluation as follows: the high-quality shale oil layer is mainly distributed on a layer a and a layer b of a big third section, the depth is 2383m and 2414m, the lithology is mainly black shale, the soft stratum is easy to collapse, wherein, an interlayer is arranged at the depth of 2400m to 2402m, the thickness is 2m, the lithology is argillaceous limestone, the hard stratum is a hard stratum, the distribution is stable, and the extension is far, so the reservoir type of the target reservoir is a thick interlayer type; determining that the target reservoir is suitable for the horizontal model according to the relation between the reservoir type and the suitable well track model; the control radius of a shale oil single well corresponding to a target reservoir stratum is generally 300m, the length L of a horizontal section corresponding to a well track is calculated to be 1200m, the well inclination angle theta is 40 degrees, the horizontal section corresponding to the well track is correspondingly drilled along the depth 2401m of the middle part of a marl interlayer, the drilling length is 1200m, after drilling is completed, the horizontal section is perforated, sand is added in sections for fracturing, the fracturing height is controlled within 18m upwards, and the fracturing height is controlled within 13m downwards.
As the well track extends to the drilling of a marlite hard formation with the thickness of 2m, the stability of the well can be kept, the well is not easy to collapse, the geological guidance can be carried out, the formation of crack bodies in the soft formations above and below the marlite interlayer after sand fracturing is facilitated, the flowing of oil gas in the soft formations into the well through the cracks is facilitated, and the oil gas recovery ratio is improved.
Referring to fig. 9, a block diagram of an apparatus for determining a borehole trajectory in a reservoir according to an exemplary embodiment of the present application is shown, the apparatus including:
an obtaining module 901, configured to obtain formation characteristic parameters corresponding to a target reservoir, where the formation characteristic parameters at least include a thickness of a hard formation included in the target reservoir;
a first determining module 902, configured to determine, according to the formation characteristic parameter, a target reservoir type corresponding to the target reservoir, where the reservoir type indicates a distribution characteristic of the hard formation in the target reservoir;
a second determining module 903, configured to determine, according to the target reservoir type, a target wellbore trajectory corresponding to the target reservoir, where the target wellbore trajectory is used to indicate a deployment position of a wellbore in the target reservoir, and distribution features of different hard formations correspond to different target wellbore trajectories.
Optionally, the second determining module 903 includes:
the first determining unit is used for determining a target borehole trajectory model corresponding to the target reservoir according to the type of the target reservoir, wherein different reservoir types correspond to different borehole trajectory models, and the target borehole trajectory model is a trajectory form corresponding to the target borehole trajectory in the target reservoir;
and the second determining unit is used for determining the target borehole trajectory corresponding to the target reservoir according to the target borehole trajectory model and the stratum characteristic parameters.
Optionally, the reservoir type comprises at least one of a no-spacer type, a thick-spacer type, and a thin-spacer type;
the first determining module 902 includes:
a third determining unit, configured to determine the non-barrier type as the target reservoir type corresponding to the target reservoir if the thickness of the hard formation included in the target reservoir is smaller than a first thickness threshold;
a fourth determining unit, configured to determine the thin-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 first thickness threshold and smaller than a second thickness threshold;
a fifth determining unit, configured to determine the thick partition 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.
Optionally, the wellbore trajectory model comprises at least one of a water tank model, a horizontal model, and a wave model;
the first determining unit is further configured to:
if the target reservoir type is the non-interlayer type, determining the water tank model as the target well track model corresponding to the target reservoir, wherein the water tank model comprises a first descending section, a first horizontal section and a first ascending section, the first descending section is connected with the first horizontal section, and the first horizontal section is connected with the first ascending section;
if the target reservoir type is the thick interlayer type, determining the horizontal model as the target borehole trajectory model corresponding to the target reservoir, wherein the horizontal model comprises a second descending section and a second horizontal section, and the second descending section is connected with the second horizontal section;
and if the target reservoir type is the thin-interval type, determining the wave model as the target borehole trajectory model corresponding to the target reservoir, wherein the wave model comprises at least one third descending section and at least one second ascending section, and the third descending section is connected with the second ascending section.
Optionally, the target wellbore trajectory model is the water tank model, and the formation characteristic parameters further include a thickness of the target reservoir and a first control radius corresponding to the target reservoir;
the second determining unit is further configured to:
and calculating the length of a first horizontal section of the target borehole trajectory corresponding to the target reservoir according to the thickness of the target reservoir and the first control radius, wherein the length of the first horizontal section is the actual length of the first horizontal section in the water tank model.
Optionally, 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;
the second determining unit is further configured to:
and calculating a second horizontal segment length of the target borehole trajectory corresponding to the target reservoir according to the second control radius, wherein the second horizontal segment length is the actual length of the second horizontal segment in the horizontal model.
Optionally, the target wellbore trajectory model is the wave model, and the formation characteristic parameters further include a thickness of the target reservoir and a third control radius corresponding to the target reservoir;
the second determining unit is further configured to:
calculating a third horizontal length of the target wellbore trajectory corresponding to the target reservoir according to the third control radius;
and calculating the inclination angle of the target borehole trajectory corresponding to the target reservoir according to the third control radius and the thickness of the target reservoir, wherein the inclination angle comprises the inclination angle of the third downward section and the inclination angle of the second upward section in the wave model.
In summary, the distribution characteristics of the hard formation in the reservoir are analyzed to determine the reservoir type corresponding to the reservoir, so that in the actual exploration process, the well track applicable to the reservoir can be determined according to the reservoir type, a proper well position can be deployed for the reservoirs with different hard formation distribution characteristics, the collapse phenomenon in the exploration process is avoided, the cost in the reservoir exploration process is reduced, and the success rate in the reservoir exploration process is improved.
It should be noted that: the device for determining a wellbore trajectory in a reservoir provided in the above embodiment is only illustrated by the division of the above functional modules, and in practical applications, the above function allocation may be completed by different functional modules according to needs, that is, the internal structure of the apparatus is divided into different functional modules, so as to complete all or part of the above description.
The application also provides a computer device, which comprises a processor and a memory, wherein at least one instruction is stored in the memory, and the at least one instruction is loaded and executed by the processor to realize the method for determining the borehole trajectory in the reservoir stratum provided by the above method embodiments. It should be noted that the computer device may be a computer device as provided in fig. 10 below.
Referring to fig. 10, a schematic structural diagram of a computer device according to an exemplary embodiment of the present application is shown. Specifically, the method comprises the following steps: the computer apparatus 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 for facilitating information transfer between various devices within the computer, and a mass storage device 1007 for storing an operating System 1013, application programs 1014, and other program modules 1015.
The basic input/output system 1006 includes a display 1008 for displaying information and an input device 1009, such as a mouse, keyboard, etc., for user input of information. Wherein a display 1008 and an input device 1009 are connected to the central processing unit 1001 via 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 input from a number of other devices, such as a keyboard, mouse, or electronic stylus. Similarly, the input-output controller 1010 also provides output to a display screen, a printer, or other type of output device.
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 CD-ROM drive.
Without loss of generality, computer readable media may comprise computer storage media and communication media. Computer storage media includes volatile and nonvolatile, removable and non-removable media implemented in any method or technology for storage of information such as computer readable instructions, data structures, program modules or other data. Computer storage media includes RAM, ROM, Erasable Programmable Read-Only Memory (EPROM), Electrically Erasable Programmable Read-Only Memory (EEPROM), flash Memory or other solid state Memory technology, CD-ROM, Digital Versatile Disks (DVD), or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices. Of course, those skilled in the art will appreciate that computer storage media is not limited to the foregoing. The system memory 1004 and mass storage device 1007 described above may be collectively referred to as memory.
The memory stores one or more programs configured to be executed by the one or more central processing units 1001, the one or more programs containing instructions for implementing the above-described shale oil production zone compartmentalization method, the central processing unit 1001 executing the one or more programs to implement the method for determining a trajectory of a borehole in a reservoir provided by the various method embodiments described above.
According to various embodiments of the present application, the computer device 1000 may also operate as a remote computer connected to a network through a network, such as the Internet. That is, the computer device 1000 may be connected to the network 1012 through the network interface unit 1011 connected to the system bus 1005, or may be connected to other types of networks or remote computer systems (not shown) using the network interface unit 1011.
The memory further includes one or more programs, one or more programs being stored in the memory, the one or more programs including steps for execution by a computer device (server) in a method for determining a trajectory of a borehole in a reservoir as provided by embodiments of the present application.
Those skilled in the art will appreciate that all or part of the steps in the methods of the above embodiments may be implemented by hardware related to instructions of a program, which may be stored in a computer readable storage medium, which may be a computer readable storage medium contained in a memory of the above embodiments; or it may be a computer-readable storage medium that exists separately and is not assembled into a computer device. The computer readable storage medium has stored therein at least one instruction, at least one program, set of codes, or set of instructions that is loaded and executed by a processor to perform the method for determining a trajectory of a wellbore in a reservoir as described above.
Optionally, the computer-readable storage medium may include: ROM, RAM, Solid State Drives (SSD), or optical disks, etc. The Random Access Memory may include a resistive Random Access Memory (ReRAM) and a Dynamic Random Access Memory (DRAM).
According to an aspect of the application, a computer program product or computer program is provided, comprising computer instructions, the computer instructions being stored in a computer readable storage medium. The computer instructions are read by a processor of a computer device from a computer-readable storage medium, and the computer instructions are executed by the processor to cause the computer device to perform the method for determining a trajectory of a borehole in a reservoir provided in the various alternative implementations of the above aspects.
It should be understood that reference to "a plurality" herein means two or more. "and/or" describes the association relationship of the associated objects, meaning that there may be three relationships, e.g., a and/or B, which may mean: a exists alone, A and B exist simultaneously, and B exists alone. The character "/" generally indicates that the former and latter associated objects are in an "or" relationship. In addition, the step numbers described herein only exemplarily show one possible execution sequence among the steps, and in some other embodiments, the steps may also be executed out of the numbering sequence, for example, two steps with different numbers are executed simultaneously, or two steps with different numbers are executed in a reverse order to the order shown in the figure, which is not limited by the embodiment of the present application.
The above description is only exemplary of the present application and should not be taken as limiting, as any modification, equivalent replacement, or improvement made within the spirit and principle of the present application should be included in the protection scope of the present application.

Claims (10)

1. A method for determining a borehole trajectory in a reservoir, the method comprising:
obtaining stratum characteristic parameters corresponding to a target reservoir, wherein the stratum characteristic parameters at least comprise the thickness of a hard stratum contained in the target reservoir;
determining a target reservoir type corresponding to the target reservoir according to the stratum characteristic parameters, wherein the reservoir type indicates the distribution characteristics of the hard stratum in the target reservoir;
and determining a target borehole trajectory corresponding to the target reservoir according to the type of the target reservoir, wherein the target borehole trajectory is used for indicating the deployment position of the borehole in the target reservoir, and the distribution characteristics of different hard formations correspond to different target borehole trajectories.
2. The method of claim 1, wherein determining a target wellbore trajectory corresponding to the target reservoir based on the target reservoir type comprises:
determining a target borehole trajectory model corresponding to the target reservoir according to the type of the target reservoir, wherein different reservoir types correspond to different borehole trajectory models, and the target borehole trajectory model is a trajectory form corresponding to the target borehole trajectory in the target reservoir;
and determining the target borehole trajectory corresponding to the target reservoir according to the target borehole trajectory model and the stratum characteristic parameters.
3. The method of claim 2, wherein the reservoir type comprises at least one of a no spacer type, a thick spacer type, a thin spacer type;
determining a target reservoir type corresponding to the target reservoir according to the formation characteristic parameters, wherein the determining comprises the following steps:
if the thickness of the hard formation contained in the target reservoir is smaller than a first thickness threshold value, determining the partition-free type as the target reservoir type corresponding to the target reservoir;
if the thickness of the hard formation layer contained in the target reservoir is larger than the first thickness threshold value and smaller than a second thickness threshold value, determining the thin-layer type as the target reservoir type corresponding to the target reservoir;
and if the thickness of the hard formation contained in the target reservoir is larger than the second thickness threshold value, determining the thick interlayer type as the target reservoir type corresponding to the target reservoir.
4. The method of claim 3, wherein the wellbore trajectory model comprises at least one of a basin model, a horizontal model, and a wave model;
determining a target borehole trajectory model corresponding to the target reservoir according to the target reservoir type, wherein the determining comprises the following steps:
if the target reservoir type is the non-interlayer type, determining the water tank model as the target well track model corresponding to the target reservoir, wherein the water tank model comprises a first descending section, a first horizontal section and a first ascending section, the first descending section is connected with the first horizontal section, and the first horizontal section is connected with the first ascending section;
if the target reservoir type is the thick interlayer type, determining the horizontal model as the target wellbore trajectory model corresponding to the target reservoir, wherein the horizontal model comprises a second descending section and a second horizontal section, and the second descending section is connected with the second horizontal section;
and if the target reservoir type is the thin-interval type, determining the wave model as the target borehole trajectory model corresponding to the target reservoir, wherein the wave model comprises at least one third descending section and at least one second ascending section, and the third descending section is connected with the second ascending section.
5. The method of claim 4, wherein the target wellbore trajectory model is the basin model, and the formation characteristic parameters further include a thickness of the target reservoir and a corresponding first control radius of the target reservoir;
determining the target borehole trajectory corresponding to the target reservoir according to the target borehole trajectory model and the formation characteristic parameters includes:
and calculating the length of a first horizontal section of the target borehole trajectory corresponding to the target reservoir according to the thickness of the target reservoir and the first control radius, wherein the length of the first horizontal section is the actual length of the first horizontal section in the water tank model.
6. The method of claim 4, wherein the target wellbore trajectory model is the horizontal model, and the formation characteristic parameters further include a corresponding second control radius for the target reservoir;
determining the target borehole trajectory corresponding to the target reservoir according to the target borehole trajectory model and the formation characteristic parameters, wherein the determining comprises:
and calculating a second horizontal segment length of the target borehole trajectory corresponding to the target reservoir according to the second control radius, wherein the second horizontal segment length is the actual length of the second horizontal segment in the horizontal model.
7. The method of claim 4, wherein the target wellbore trajectory model is the wave model, the formation characteristic parameters further include a thickness of the target reservoir and a corresponding third control radius of the target reservoir;
determining the target borehole trajectory corresponding to the target reservoir according to the target borehole 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;
and calculating the inclination angle of the target borehole trajectory corresponding to the target reservoir according to the third control radius and the thickness of the target reservoir, wherein the inclination angle comprises the inclination angle of the third lower section and the inclination angle of the second upper section in the wave model.
8. An apparatus for determining a borehole trajectory in a reservoir, the apparatus comprising:
the system comprises an acquisition module, a storage module and a processing module, wherein the acquisition module is used for acquiring stratum characteristic parameters corresponding to a target reservoir, and the stratum characteristic parameters at least comprise the thickness of a hard stratum contained in the target reservoir;
the first determination module is used for determining a target reservoir type corresponding to the target reservoir according to the stratum characteristic parameters, wherein the reservoir type indicates the distribution characteristics of the hard stratum in the target reservoir;
and the second determination module is used for determining a target borehole trajectory corresponding to the target reservoir according to the type of the target reservoir, wherein the target borehole trajectory is used for indicating the deployment position of the borehole in the target reservoir, and the distribution characteristics of different hard formations correspond to different target borehole trajectories.
9. A computer device comprising a processor and a memory, the memory having stored therein at least one instruction that is loaded and executed by the processor to perform a method of determining a well trajectory in a reservoir as claimed in any one of claims 1 to 7.
10. A computer readable storage medium having stored therein at least one instruction which is loaded and executed by a processor to perform the method of determining a well bore trajectory in a reservoir as claimed in any one of claims 1 to 7.
CN202110088538.2A 2021-01-22 2021-01-22 Method, device and equipment for determining borehole trajectory in oil reservoir stratum and storage medium Pending CN114810047A (en)

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