CN115110948A

CN115110948A - Horizontal well trajectory analysis method, device, equipment and storage medium

Info

Publication number: CN115110948A
Application number: CN202110285373.8A
Authority: CN
Inventors: 邓亚; 李勇; 胡丹丹; 张文旗; 郭睿; 田中元; 许家铖; 马瑞程; 陈一航; 徐炜
Original assignee: Petrochina Co Ltd
Current assignee: Petrochina Co Ltd
Priority date: 2021-03-17
Filing date: 2021-03-17
Publication date: 2022-09-27

Abstract

Provided herein are a horizontal well trajectory analysis method, apparatus, device, and storage medium, wherein the method comprises: dividing a stratum where a target section of a horizontal well is located to obtain a plurality of first layers and parameter data of each first layer; dividing the track of the target section according to the parameter data of the first hierarchy to obtain a plurality of unit tracks, wherein each unit track corresponds to one first hierarchy; and projecting each unit track according to the first layered parameter data to obtain an analysis image of the target section relative to the stratum. The method provided by the invention is simple and convenient to operate, and the images are not easy to generate dislocation and overlap; the obtained analysis image can show the track trend of the target zone of the horizontal well, can also visually show the relative position relation of each zone in the stratum, and has important guiding values for geological mapping and horizontal well production dynamic analysis.

Description

Horizontal well trajectory analysis method, device, equipment and storage medium

Technical Field

The invention relates to the technical field of petroleum and natural gas exploration and development, in particular to a horizontal well trajectory analysis method, device, equipment and storage medium.

Background

As development progresses, particularly towards non-conventional fields, more and more oil fields are developed by adopting horizontal wells or highly-deviated wells in order to obtain higher production. Because horizontal well information has abundant transverse information, compared with the traditional vertical well or directional well, the horizontal well has incomparable advantages in describing the transverse change of the reservoir stratum. Due to the heterogeneity of reservoirs and the limitation of geosteering, the track of the horizontal well swings up and down in a target oil reservoir, so that the physical properties of the horizontal section of the horizontal well are greatly changed. And oil reservoir analysis usually focuses on the corresponding relation of the horizontal section track in the relative position of the oil reservoir and the injection production in a well pattern or a well row, and the longitudinal position of a single well needs to be analyzed well by well. The traditional method is to cut individual wells or well-row profiles, or project wells of different well-rows into the same well profile. However, these methods have limitations, in that the steps of cutting a profile of a single well are complicated, the integrity is lacking, the whole appearance of the well cannot be reflected by only one vertical profile of the well, and other images such as horizontal projection of the well are required to be matched; and single well profiles cannot be used to analyze the relative position of the well trajectory to the target formation. If the projection is performed according to the well row, the defect of dislocation of the projection of the well track exists due to the influence of the fluctuation of the structure. Therefore, a faster and more intuitive method is urgently needed to be created for oil reservoir analysis, and the horizontal well track and the target reservoir position are visually displayed to accurately judge the positions of different well sections.

Disclosure of Invention

Aiming at the problems in the prior art, the invention aims to provide a horizontal well trajectory analysis method to overcome the defect that the relative position relationship between a well trajectory and an oil reservoir layer cannot be displayed conveniently and intuitively in the conventional well trajectory analysis method.

In order to solve the technical problems, the specific technical scheme is as follows:

in a first aspect, a method for horizontal well trajectory analysis is provided herein, comprising:

dividing a stratum where a target section of a horizontal well is located to obtain a plurality of first layers and parameter data of each first layer;

dividing the track of the target section according to the parameter data of the first hierarchy to obtain a plurality of unit tracks, wherein each unit track corresponds to one first hierarchy;

and projecting each unit track according to the first layered parameter data to obtain an analysis image of the target section relative to the stratum.

Specifically, the parameter data of the first hierarchy includes layer interface data between two adjacent first hierarchies, and the track of the target section is segmented according to the parameter data of the first hierarchy to obtain a plurality of unit tracks, including:

according to the layer interface data, acquiring an intersection point of a track of the target section and a layer interface between two adjacent first layers;

and segmenting the track of the target section according to the intersection points to obtain a plurality of unit tracks.

Further, the projecting each unit track according to the parameter data of the first hierarchy to obtain an analysis image of the target section with respect to the stratum includes:

calculating projection data of each unit track in a second layer according to the parameter data of the first layer, wherein the number of layers of the second layer is equal to that of the first layer, and the thickness of each second layer is equal;

and projecting the unit tracks into the second hierarchies according to the projection data.

Further, the parameter data of the first layer further includes thickness data of each first layer and position relation data of each first layer relative to the formation layer, and the calculating projection data of each unit trajectory in the second layer according to the parameter data of the first layer includes:

calculating basic longitudinal data of the unit track in the second layer according to the position relation data;

and calculating relative longitudinal data of the unit track in the second layering according to the thickness data and the layer interface data.

Specifically, the calculating the relative longitudinal data of the unit trajectory in the second layer according to the thickness data and the layer interface data includes:

calculating the distance between each point in the unit track and the layer interface adjacent to each point according to the layer interface data;

and calculating relative longitudinal data of each point in the unit track according to the distance and the thickness data.

Preferably, the method further comprises:

coloring the analysis image.

In particular, the target segment may be determined by the steps comprising:

determining the starting point of the target section according to the end point of the horizontal well track entering a target layer/layer group, and determining the end point of the target section according to the end point of the horizontal well track leaving the target layer/layer group;

or taking the end point of the first preset distance from the horizontal well track to the top of the target layer/layer group as the starting point, and taking the end point of the second preset distance from the horizontal well track to the bottom of the target layer/layer group as the end point of the target section.

In a second aspect, there is also provided herein a horizontal well trajectory analysis device comprising:

the stratum dividing module is used for dividing the stratum where the target section of the horizontal well is located to obtain a plurality of first layers and parameter data of the first layers;

the track segmentation module is used for segmenting the track of the target section according to the parameter data to obtain a plurality of unit tracks, and each unit track corresponds to one first layering;

and the projection module is used for projecting each unit track according to the parameter data to obtain an analysis image of the target section relative to the stratum.

In a third aspect, a computer device is further provided herein, which includes a memory, a processor, and a computer program stored on the memory and executable on the processor, and when the processor executes the computer program, the horizontal well trajectory analysis method provided in the foregoing technical solution is implemented.

In a fourth aspect, a computer-readable storage medium is further provided herein, where the computer-readable storage medium stores a computer program, and the computer program is executed by a processor to implement the horizontal well trajectory analysis method according to the above technical solution.

By adopting the technical scheme, the method, the device, the equipment and the storage medium for analyzing the horizontal well track are simple and convenient to operate, and the images are not easy to generate dislocation and overlapping; the obtained analysis image can show the track trend of the target section of the horizontal well, can also visually show the relative position relation of each section in the stratum, and has important guiding values for geological mapping and production dynamic analysis of the horizontal well.

In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.

Drawings

In order to more clearly illustrate the embodiments or technical solutions in the prior art, the drawings used in the embodiments or technical solutions in the prior art are briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present disclosure, and other drawings can be obtained by those skilled in the art without creative efforts.

Fig. 1 shows a schematic flow diagram of a horizontal well trajectory analysis method provided in an embodiment herein;

FIG. 2 is a flow chart illustrating the calculation of projection data of unit trajectories in a second hierarchy;

fig. 3 is a schematic flow chart illustrating that a horizontal well trajectory analysis image is obtained by applying the horizontal well trajectory analysis method provided by the embodiment of the present disclosure;

FIG. 4 is a schematic structural diagram of a horizontal well trajectory analysis device;

FIG. 5 shows a schematic of the trajectories of the injection and production wells in the well pattern (well row);

FIG. 6 shows a schematic flow chart for obtaining 0-4H injection and production well analysis images in a well pattern (well row);

FIG. 7 shows an analytical image of a well pattern (well row);

fig. 8 shows a computer device.

Description of the symbols of the drawings:

41. a formation partitioning module;

42. a trajectory segmentation module;

43. a projection module;

802. a computer device;

804. a processor;

806. a memory;

808. a drive mechanism;

810. an input/output module;

812. an input device;

814. an output device;

816. a presentation device;

818. a graphical user interface;

820. a network interface;

822. a communication link;

824. a communication bus.

Detailed Description

The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments herein without making any creative effort, shall fall within the scope of protection.

It should be noted that the terms "first," "second," and the like in the description and claims herein and in the above-described drawings are used for distinguishing between similar elements and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used is interchangeable under appropriate circumstances such that the embodiments herein described are capable of operation in sequences other than those illustrated or described herein. Moreover, the terms "comprises," "comprising," and "having," and any variations thereof, are intended to cover a non-exclusive inclusion, such that a process, method, apparatus, article, or device that comprises a list of steps or elements is not necessarily limited to those steps or elements expressly listed, but may include other steps or elements not expressly listed or inherent to such process, method, article, or device.

The development technology of the horizontal well is gradually improved, the number of the horizontal wells is greatly increased, new requirements are provided for well logging while the horizontal well is developed in a large scale, and research on a horizontal well logging evaluation method of a system needs to be developed urgently, wherein the research on the relative position of a well track in a reservoir stratum and the research on the corresponding relation of well pattern or in-bank injection production are included.

The traditional method of cutting a single well or a well array profile and projecting wells of different well arrays into the same well profile can only obtain well tracks, has complex steps and poor integrity, and has poor reflecting capacity on the relative positions of the well tracks and an oil reservoir stratum. Therefore, a faster and more intuitive method is urgently needed to be created for oil reservoir analysis, and the horizontal well track and the target reservoir position are visually displayed to accurately judge the positions of the reservoirs in different well sections.

In order to solve the above problems, the embodiments herein provide a horizontal well trajectory analysis method, which can intuitively show the horizontal well trend and the position relationship of each section of the horizontal well with respect to the reservoir stratum of the oil deposit. Fig. 1 is a schematic flow diagram of a horizontal well trajectory analysis method provided in an embodiment herein, and the present specification provides the method operation steps as described in the embodiment or the flow diagram, but may include more or less operation steps based on conventional or non-inventive labor. The order of steps recited in the embodiments is merely one manner of performing the steps in a multitude of orders and does not represent the only order of execution. When an actual system or apparatus product executes, it can execute sequentially or in parallel according to the method shown in the embodiment or the figures. Specifically, as shown in fig. 1, the method may include:

s101: dividing a stratum where a target section of a horizontal well is located to obtain a plurality of first layers and parameter data of each first layer;

in the present description, the horizontal well refers to a special well having a maximum inclination angle of 90 ° (generally not less than 86 °) and maintaining a horizontal well section of a certain length in the target zone. The horizontal well is suitable for thin oil-gas reservoirs or fractured oil-gas reservoirs, and the exposed area of the oil-gas reservoirs can be increased. A target section of a horizontal well is herein a section of a well trajectory that reaches or approaches a horizontal attitude and maintains a certain length.

As shown in fig. 3, the schematic flow chart of the horizontal well trajectory analysis method provided by the embodiment of the present specification to obtain an analysis image of a horizontal well trajectory is shown, and as shown in (a) in fig. 3, a winding and undulating curve is a target section of a horizontal well to be analyzed; and dividing the stratum where the target section of the horizontal well is located to obtain three first layers, namely Layer1, Layer2 and Layer 3. Layer1, Layer2 and Layer3 are arranged from top to bottom in the figure, corresponding to buried depths from shallow to deep, i.e. Layer1 is the Layer of the three first layers closest to the earth's surface and Layer3 is the one of the three first layers furthest from the earth's formation. In addition, in the embodiment of the specification, the layer thicknesses of the three first sub-layers are different, and the thicknesses of different areas in the same first sub-layer are also different.

S102: dividing the track of the target section according to the parameter data of the first hierarchy to obtain a plurality of unit tracks, wherein each unit track corresponds to one first hierarchy;

as shown in fig. 3 (a), the target segment is divided into five Unit trajectories according to the first hierarchical parameter data, i.e., Unit1, Unit2, Unit3, Unit4, and Unit 5; each unit track corresponds to one of the first hierarchies: unit1 corresponds to Layer3, Unit2 corresponds to Layer2, Unit3 corresponds to Layer1, Unit4 corresponds to Layer2, and Unit5 corresponds to Layer 1. Different cell tracks may correspond to the same first hierarchical layer, but adjacent two cell tracks are necessarily at different first hierarchical layers.

S103: and projecting each unit track according to the parameter data of the first layering to obtain an analysis image of the target section relative to the stratum.

That is, the unit tracks in fig. 3 (a) are projected according to the parameter data of each first layer, and fig. 3 (b) is obtained.

According to the horizontal well trajectory analysis method provided by the embodiment of the specification, a target section of a horizontal well is divided according to a plurality of first layers obtained by dividing a stratum; then, projecting a plurality of unit tracks obtained by segmentation, so that an analysis image obtained by projection not only can show the track trend of a target section of the horizontal well, but also can visually show the relative position relation between each unit track and each first layer; the method is simple to operate, the obtained analysis images cannot be dislocated or overlapped, and the method has important guiding values for geological mapping and horizontal well production dynamic analysis.

In the embodiment of the present specification, in order to more intuitively reveal the relative position relationship between the target section of the horizontal well and the formation (i.e. the reservoir), preferably, the method further includes:

s104: coloring the analysis image.

The colored analysis image is shown in (c) in fig. 3, and it should be noted that in the embodiment of the present specification, each unit track is colored in gray with different shades only by way of example, and the coloring range in the present specification is that each unit track and the top layer of the stratum where the target section is located. The location of the formation where the cell trajectory is located is characterized by the different depths of the gray color: the cell trace Unit1 and the space above it are colored in the lightest gray, which means that the cell trace Unit1 is located at the first hierarchical level where it is most buried; cell trace Unit3 and the space above it are colored in the darkest gray to characterize cell trace Unit3 at the first level of burial lightest, and so on; of course, the depth of the buried layer and the depth of the filling color may have a corresponding relationship different from that in the embodiment of the present specification.

The above is only one possible example, and in addition to this, there are many different ways of coloring, such as:

different coloration ranges were used: the coloring range of each unit track can be from the unit track and the space below the unit track, namely the unit track to the bottom end of the lowest one of the first layers; filling with different patterns: diagonal patterns, grid patterns, corrugated patterns, circle patterns and the like, and different filling patterns are respectively corresponding to different first layers where different unit tracks are located; different colors can also be used for filling: the unit tracks are red, orange, yellow and the like, different first layers where the unit tracks are located are represented by different colors, and the position depth of the unit tracks corresponding to the reservoir layer is represented by color gradient; it is also possible to color only the lines of the unit tracks themselves.

It should be noted that, in the embodiment of the present specification, the division of the stratum where the target section of the horizontal well is located may be performed according to geological information and/or reservoir performance of the stratum, for example, according to lithology, lithofacies and collected fossil of the stratum; and one or more of parameters such as energy storage property, buried depth and the like are combined for division.

In the embodiment of the present description, the trajectory of the target section of the horizontal well may be obtained as follows:

acquiring pre-stored track data of a horizontal well; the pre-stored track data of the horizontal well can be well track data stored in the process from horizontal well exploration design to excavation construction. The pre-stored trajectory data of the horizontal well may be obtained by making a plumb line for each point on a spatial curve of the trajectory of the horizontal well, connecting lines of the plumb lines forming a curved surface, and after the curved surface is unfolded into a plane, the trajectory of the horizontal well, which is originally a spatial curve, is converted into a trajectory in the plane, so as to obtain a bending curve as shown in fig. 3 (a).

And acquiring the track of the target section according to the horizontal well track data.

The target section of the horizontal well may be determined according to the following steps:

determining a starting point of the target section according to an end point of the horizontal well track entering a target layer or a target layer group, and determining an end point of the target section according to an end point of the horizontal well track leaving the target layer or the target layer group;

or taking the end point of the first preset distance from the horizontal well track to the top of the target layer or the target layer group as the starting point, and taking the end point of the second preset distance from the horizontal well track to the bottom of the target layer or the target layer group as the end point of the target section.

Of course, other determination manners are also possible, as shown in fig. 3, wherein the starting point of the horizontal well target section (the left end point of the curve in fig. 3 (a)) is a point at a second preset distance from the bottom of the target interval, and the ending point of the horizontal well target section (the right end point of the curve in fig. 3 (a)) is a point not separated from the target interval.

In this embodiment, the parameter data of the first layer includes layer interface data between two adjacent first layers, and in some possible embodiments, step S102: segmenting the track of the target section according to the first hierarchical parameter data to obtain a plurality of unit tracks, which specifically comprises:

That is, as shown in fig. 3 (a), the track located between two adjacent intersection points is one unit track, and thus two adjacent unit tracks are necessarily located at different first hierarchies.

Step S103: the projecting each unit track according to the first layered parameter data to obtain an analysis image of the target section about the stratum further includes:

As shown in fig. 3 (b) and 3 (c), the three second split layers are Layer1 ', Layer2 ' and Layer3 ', respectively. Each second Layer corresponds to the first Layer, namely Layer 1' corresponds to Layer 1; layer2 'corresponds to Layer2 and Layer 3' corresponds to Layer 3.

It should be noted that the thicknesses of the second sublayers are the same, and the thicknesses of different areas in the same second sublayer are also the same, so as to uniformly display an analysis image of a horizontal well trajectory. Because the original layer thickness difference of each first layering may be large, and the layer thickness of the same first layering may have large fluctuation, the horizontal well track in the first layering with the smaller thickness may be difficult to display after projection, and the second layering with uniform thickness is beneficial to compressing data volume, so that the target sections of the horizontal well in the first layering with different layer thicknesses can be well displayed.

In this embodiment of the present specification, the parameter data of the first layer further includes thickness data of each first layer and position relation data of each first layer with respect to the formation layer, and as shown in fig. 2, calculating projection data of each unit trajectory in the second layer according to the parameter data of the first layer includes:

s201: calculating basic longitudinal data of the unit track in the second layer according to the position relation data;

the position relation data includes the position relation between the first hierarchy of the unit track and all the first hierarchies, that is, the first hierarchy of the unit track is located at the second hierarchy of all the first hierarchies, so that the basic longitudinal data can be calculated by the following formula:

i ₀ ＝i-1；

wherein i ₀ Longitudinal data is the basis of the unit track; i is the number of layers in all the first hierarchies of the first hierarchy in which the unit track is located, i.e., the unit track is located in the ith first hierarchy (in the top-down direction in the figure).

S202: and calculating relative longitudinal data of the unit track in the second layering according to the thickness data and the layer interface data.

In some preferred embodiments, step S202: calculating relative longitudinal data of the unit trajectory in the second hierarchical layer according to the thickness data and the layer interface data, including:

calculating the distance between each point in the unit track and the layer interface adjacent to the point according to the layer interface data;

the layer interface data is interface data between two adjacent first layers. Optionally, calculating a vertical distance from each point in the unit trajectory to the top of the first hierarchical layer, and recording the distance as d _i . In some alternative embodiments, the distance may also be expressed in terms of the distance of each point from the bottom of the first hierarchical layer.

Calculating relative longitudinal data of each point in the unit track according to the distance and the thickness data;

the thickness data may include thickness data at different regions of each first segment, a maximum thickness of the first segment, an average thickness of the first segment, etc.; note that the relative longitudinal data is R _i Then the relative longitudinal data can be calculated by the following formula:

wherein W _i Is the maximum thickness of the ith first segment; d _i The vertical distance from each point in the unit track to the top of the first layering layer of the unit track;

of course W _i The maximum thickness of the ith first segment, or a value obtained by weighting and calculating the maximum thickness and the average thickness, etc. may also be used for representation.

So that the projection data of each unit track in the corresponding second hierarchy is:

Z _i ＝(i-1)+R _i ；

wherein Z is _i Is the projection data of a point in the element trajectory in the second tier corresponding thereto.

It should be noted that the projection data above is calculated by using projection data of the unit trajectory in the vertical direction, and the projection data in the horizontal direction is represented by using the horizontal distance of the unit trajectory in the first hierarchy, that is, the horizontal distance of the unit trajectory in the first hierarchy may be equal to the horizontal distance of the unit trajectory in the second hierarchy. The horizontal distance of the unit trajectory in the first hierarchical layer may also be scaled down to obtain the horizontal distance of the unit trajectory in the second hierarchical layer.

An embodiment of the present specification further provides a horizontal well trajectory analysis device, as shown in fig. 4, which is a schematic structural diagram of the device, and the device includes:

the stratum dividing module 41 is used for dividing the stratum where the target section of the horizontal well is located to obtain a plurality of first layers and parameter data of the first layers;

a track segmentation module 42, configured to segment a track of the target segment according to the parameter data to obtain a plurality of unit tracks, where each unit track corresponds to one first hierarchical layer;

and a projection module 43, configured to project each unit according to the parameter data, and obtain an analysis image of the target segment with respect to the formation.

On the basis of the horizontal well trajectory analysis method provided above, an embodiment of the present specification further provides an analysis method for a corresponding relationship between injection and production well trajectories in a well pattern (well row), as shown in fig. 5, a schematic diagram of each injection and production well trajectory in a certain well pattern (well row) is shown, as shown in the figure, the injection and production well includes 3 well rows, and (a) in fig. 5 is a zeroth well row, specifically includes 2 injection and production wells 0-3H (H represents horizons, which means horizontal wells) and 0-4H; fig. 5 (b) is a first well row, which specifically includes 3 injection-production wells, 1-2H, 1-3H, and 1-4H, respectively; and as shown in fig. 5 (c), is the second well row, and specifically comprises 2 injection and production wells, 2-8H and 2-7H respectively.

The method comprises the following steps:

s1: acquiring track data of each injection and production well in a well pattern (well row), wherein the track data not only comprises tracks of target sections of the injection and production wells, but also comprises position relations among the injection and production wells; such as the position relationship between the zeroth well row and the first well row, the position relationship between the 0-3H injection well and the 0-4H injection well, and the like.

S2: dividing the stratum where the target section of each injection and production well is located to obtain a plurality of first layers and parameter data of each first layer;

it should be noted that when the first layer is divided, the first layers obtained by dividing each injection and production well are the same, that is, in fig. 3, 5 first layers are obtained by dividing the stratum where each injection and production well is located at different well rows, and from top to bottom, the 5 first layers are sequentially marked as A, B, C, D and E. The maximum layer thickness of each first layer was 4m, 4.5m, 5.2m, 3.5m and 4m, respectively.

S3: dividing the track of each injection and production well according to the layer interface data of the first layering to obtain a plurality of unit tracks; each of the unit tracks corresponds to a first layer, and as shown in fig. 6, taking injection wells 0 to 4H as an example, the track of the target section is divided to obtain 7 unit tracks.

S4: and projecting each unit track of each injection and production well to the same plane according to the track data and the track data to obtain an analysis image of a well pattern (well row).

In this embodiment of the present description, preferably, an analysis image of any injection well is obtained by using a horizontal well trajectory analysis method for the injection well, as shown in fig. 6 (a), a first unit trajectory of a target section of the injection well from left to right is located in a third first layer (i.e., layer C), and for any point in the unit trajectory, the relative longitudinal data of the unit trajectory is d _i 5.2; the projection data in the longitudinal direction is (3-1) + d _i /5.2. By analogy, projection data of all unit tracks of the 0-4H injection well track are obtained and projected into the second layers A ', B ', C ', D ' and E ', so that an analysis image shown in (B) of fig. 6 is obtained, and the image shown in (C) of fig. 6 is obtained by coloring the (B) of fig. 6.

And then according to the projection images of the injection and production wells and the position relationship among the injection and production wells, obtaining a well pattern (well row) analysis image, as shown in fig. 7. It should be noted that the "up", "down", "left" and "right" orientations illustrated in fig. 7 represent the north, south, west and east, respectively, to characterize the spatial orientation of the well pattern (well rows).

As shown in fig. 8, for a computer device provided for embodiments herein, the computer device 802 may include one or more processors 804, such as one or more Central Processing Units (CPUs), each of which may implement one or more hardware threads. The computer device 802 may also include any memory 806 for storing any kind of information, such as code, settings, data, etc. For example, and without limitation, memory 806 may include any one or more of the following in combination: any type of RAM, any type of ROM, flash memory devices, hard disks, optical disks, etc. More generally, any memory may use any technology to store information. Further, any memory may provide volatile or non-volatile retention of information. Further, any memory may represent fixed or removable components of computer device 802. In one case, when the processor 804 executes the associated instructions, which are stored in any memory or combination of memories, the computer device 802 can perform any of the operations of the associated instructions. The computer device 802 also includes one or more drive mechanisms 808, such as a hard disk drive mechanism, an optical disk drive mechanism, etc., for interacting with any memory.

Computer device 802 may also include an input/output module 810(I/O) for receiving various inputs (via input device 812) and for providing various outputs (via output device 814)). One particular output mechanism may include a presentation device 816 and an associated graphical user interface 818 (GUI). In other embodiments, input/output module 810(I/O), input device 812, and output device 814 may also be excluded, as just one computer device in a network. Computer device 802 can also include one or more network interfaces 820 for exchanging data with other devices via one or more communication links 822. One or more communication buses 824 couple the above-described components together.

Communication link 822 may be implemented in any manner, such as over a local area network, a wide area network (e.g., the Internet), a point-to-point connection, etc., or any combination thereof. The communication link 822 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

Corresponding to the methods in fig. 1-3, 5-7, the embodiments herein also provide a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, performs the steps of the above-mentioned method.

Embodiments herein also provide computer readable instructions, wherein when the instructions are executed by a processor, the program causes the processor to perform the method as in fig. 1-3, 5-7.

It should be understood that, in various embodiments herein, the sequence numbers of the above-mentioned processes do not mean the execution sequence, and the execution sequence of each process should be determined by its function and inherent logic, and should not constitute any limitation to the implementation process of the embodiments herein.

Embodiments herein also provide a computer-readable storage medium storing a computer program which, when executed by a processor, implements the steps of

It should also be understood that, in the embodiments herein, the term "and/or" is only one kind of association relation describing an associated object, and means that there may be three kinds of relations. For example, a and/or B, may represent: a exists alone, A and B exist simultaneously, and B exists alone. In addition, the character "/" herein generally indicates that the former and latter associated objects are in an "or" relationship.

Those of ordinary skill in the art will appreciate that the elements and algorithm steps of the examples described in connection with the embodiments disclosed herein may be embodied in electronic hardware, computer software, or combinations of both, and that the components and steps of the examples have been described in a functional general in the foregoing description for the purpose of illustrating clearly the interchangeability of hardware and software. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the implementation. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present disclosure.

It is clear to those skilled in the art that, for convenience and brevity of description, the specific working processes of the above-described systems, apparatuses and units may refer to the corresponding processes in the foregoing method embodiments, and are not described herein again.

In the several embodiments provided herein, it should be understood that the disclosed system, apparatus, and method may be implemented in other ways. For example, the above-described apparatus embodiments are merely illustrative, and for example, the division of the units is only one type of logical functional division, and other divisions may be realized in practice, for example, multiple units or components may be combined or integrated into another system, or some features may be omitted, or not executed. In addition, the shown or discussed mutual coupling or direct coupling or communication connection may be an indirect coupling or communication connection through some interfaces, devices or units, and may also be an electric, mechanical or other form of connection.

The units described as separate parts may or may not be physically separate, and parts displayed as units may or may not be physical units, may be located in one place, or may be distributed on a plurality of network units. Some or all of the units can be selected according to actual needs to achieve the purposes of the embodiments herein.

In addition, functional units in the embodiments herein may be integrated into one processing unit, or each unit may exist alone physically, or two or more units are integrated into one unit. The integrated unit may be implemented in the form of hardware, or may also be implemented in the form of a software functional unit.

The integrated unit, if implemented in the form of a software functional unit and sold or used as a stand-alone product, may be stored in a computer readable storage medium. Based on such understanding, the technical solutions of the present invention may be implemented in a form of a software product, which is stored in a storage medium and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device) to execute all or part of the steps of the methods described in the embodiments of the present invention. And the aforementioned storage medium includes: a U-disk, a removable hard disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a magnetic disk, or an optical disk, and various media capable of storing program codes.

The principles and embodiments of the present disclosure are explained in detail by using specific embodiments, and the above description of the embodiments is only used to help understanding the method and its core idea; meanwhile, for a person skilled in the art, according to the idea of the present disclosure, there may be variations in the specific embodiments and the application scope, and in summary, the content of the present disclosure should not be construed as a limitation to the present disclosure.

Claims

1. A horizontal well trajectory analysis method is characterized by comprising the following steps:

2. The horizontal well trajectory analysis method according to claim 1, wherein the parameter data of the first layer includes layer interface data between two adjacent first layers, and the trajectory of the target section is segmented according to the parameter data of the first layer to obtain a plurality of unit trajectories, including:

3. The horizontal well trajectory analysis method according to claim 2, wherein the projecting each of the unit trajectories according to the first stratified parameter data comprises:

4. The horizontal well trajectory analysis method according to claim 3, wherein the parameter data of the first stratigraphic layer further comprises thickness data of each first stratigraphic layer and position relation data of each first stratigraphic layer relative to the formation;

the calculating projection data of each unit track in the second hierarchy according to the parameter data of the first hierarchy comprises:

5. The horizontal well trajectory analysis method according to claim 4, wherein calculating relative longitudinal data of the unit trajectory in the second layer from the thickness data and the layer interface data comprises:

6. The horizontal well trajectory analysis method according to claim 1, further comprising:

coloring the analysis image.

7. The horizontal well trajectory analysis method of claim 1, wherein the target zone is determined by the steps comprising:

8. A horizontal well trajectory analysis device, comprising:

9. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein the processor when executing the computer program implements the horizontal well trajectory analysis method according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that it stores a computer program which, when executed by a processor, implements the horizontal well trajectory analysis method according to any one of claims 1 to 7.