CN109343113B

CN109343113B - Method and device for predicting oil and gas reservoir position

Info

Publication number: CN109343113B
Application number: CN201811308442.7A
Authority: CN
Inventors: 张津宁; 李宏军; 付立新; 楼达; 冯建园; 赵勇刚; 李会慎; 杨子玉; 段润梅; 崔宇; 王辉; 王鑫
Original assignee: Petrochina Co Ltd
Current assignee: Petrochina Co Ltd
Priority date: 2018-11-05
Filing date: 2018-11-05
Publication date: 2020-06-09
Anticipated expiration: 2038-11-05
Also published as: CN109343113A

Abstract

The invention discloses a method and a device for predicting a position of an oil-gas reservoir, and belongs to the technical field of oil-gas exploration. The method comprises the following steps: acquiring a seismic section of a target area, and determining a fault line of the seismic section; determining statics pressures at a plurality of locations on a fault line of the seismic profile; determining a component of the lithostatic pressure at each of the plurality of locations in a direction perpendicular to the fault line; determining a difference value between the static rock pressure of each position and a component of the static rock pressure in a direction perpendicular to the fault line; performing curve fitting according to the difference value and the depth value corresponding to each position to obtain a first relation function of the depth value and the difference value on the fault line; and determining a minimum value of the difference value in the first relation function, and predicting the position of the oil and gas reservoir according to the position on the fault line corresponding to the minimum value. By adopting the method and the device, the technical problem of predicting the oil and gas reservoir can be effectively solved.

Description

Method and device for predicting oil and gas reservoir position

Technical Field

The invention relates to the technical field of oil and gas exploration, in particular to a method and a device for predicting an oil and gas reservoir position.

Background

Oil and gas production first requires oil and gas exploration to locate the reservoir, and a fault reservoir is a type of reservoir widely distributed on the earth's crust. Therefore, it is important in oil and gas exploration how to predict the location of a faulted reservoir.

The method for predicting the location of a fault reservoir in the related art estimates the location of the fault reservoir through lithological characteristics on both sides of the fault. For example, assuming that the lithological characteristics of one side of the fault are loose and the lithological characteristics of the other side are tight, the reservoir is likely to be located on the side where the lithological characteristics are loose.

In the process of implementing the invention, the inventor finds that the related art has at least the following problems:

if lithological characteristics on two sides of the fault are consistent, the method in the related art cannot judge the position of the fault oil and gas reservoir.

Disclosure of Invention

In order to solve the technical problems in the related art, the embodiments of the present invention provide a method and an apparatus for predicting a location of a hydrocarbon reservoir. The technical scheme of the method and the device for predicting the position of the oil and gas reservoir is as follows:

in a first aspect, there is provided a method of predicting a location of a hydrocarbon reservoir, the method comprising:

acquiring a seismic section of a target area, and determining a fault line of the seismic section;

determining statics pressures at a plurality of locations on a fault line of the seismic profile;

determining a component of the lithostatic pressure at each of the plurality of locations in a direction perpendicular to the fault line;

determining a difference value between the static rock pressure of each position and a component of the static rock pressure in a direction perpendicular to the fault line;

performing curve fitting according to the difference value and the depth value corresponding to each position to obtain a first relation function of the depth value and the difference value on the fault line;

and determining a minimum value of the difference value in the first relation function, and predicting the position of the oil and gas reservoir according to the position on the fault line corresponding to the minimum value.

Optionally, the determining a component of the lithostatic pressure at each of the plurality of locations in a direction perpendicular to the fault line includes:

determining an angle between a tangent to each of the plurality of locations on a fault line of the seismic profile and a horizontal line;

and determining the component of the static rock pressure of each position in the plurality of positions in the direction perpendicular to the fault line based on the included angle between the static rock pressure of each position and the tangent line of each position and the horizontal line.

Optionally, after determining the lithostatic pressure at a plurality of positions on the fault line of the seismic profile, the method further includes:

performing curve fitting according to the static rock pressure and the depth value corresponding to each position to obtain a second relation function of the depth value and the static rock pressure on the fault line, and displaying a curve corresponding to the second relation function;

the determining, based on the fault line of the seismic profile, a component of the lithostatic pressure at each of the plurality of locations in a direction perpendicular to the fault line further comprises:

and performing curve fitting according to the component and the depth value of the static rock pressure at each position in the direction vertical to the fault line to obtain a third relation function of the depth value and the component on the fault line, and displaying a curve corresponding to the third relation function.

Optionally, performing curve fitting according to the component and the depth value of the static rock pressure at each position in the direction perpendicular to the fault line to obtain a third relation function of the depth value and the component on the fault line, and after displaying a curve corresponding to the third relation function, further including:

and highlighting a part between the curve corresponding to the second relation function and the curve corresponding to the third relation function.

Optionally, after determining the minimum value of the difference in the relationship function and predicting the position of the hydrocarbon reservoir according to the position on the fault line corresponding to the minimum value, the method further includes:

and marking and displaying the depth value corresponding to the minimum value.

Optionally, the acquiring a seismic profile of the target area, after determining a fault line of the seismic profile, further includes:

displaying the seismic profile;

after determining the minimum value of the difference value in the first relation function and predicting the position of the oil and gas reservoir according to the position on the fault line corresponding to the minimum value, the method further comprises the following steps:

the location of the reservoir is marked in the seismic profile.

In a second aspect, there is provided an apparatus for predicting a location of a hydrocarbon reservoir, the apparatus comprising:

the acquisition module is used for acquiring a seismic profile of a target area and determining a fault line of the seismic profile;

a determination module for determining the statics pressure at a plurality of locations on a fault line of the seismic profile, determining the component of the statics pressure at each of the plurality of locations in a direction perpendicular to the fault line, determining the difference between the statics pressure at each of the locations and the component of the statics pressure in the direction perpendicular to the fault line;

the fitting module is used for performing curve fitting according to the difference value and the depth value corresponding to each position to obtain a first relation function of the depth value and the difference value on the fault line;

and the prediction module is used for determining the minimum value of the difference value in the first relation function and predicting the position of the oil and gas reservoir according to the position on the fault line corresponding to the minimum value.

Optionally, the determining module is configured to:

Optionally, the apparatus further comprises:

and the display module is used for performing curve fitting according to the static rock pressure and the depth value corresponding to each position to obtain a second relation function of the depth value and the static rock pressure on the fault line, displaying a curve corresponding to the second relation function, performing curve fitting according to the component and the depth value of the static rock pressure at each position in the direction perpendicular to the fault line, obtaining a third relation function of the depth value and the component on the fault line, and displaying the curve corresponding to the third relation function.

Optionally, the display module is further configured to:

and marking and displaying the depth value corresponding to the minimum value.

Optionally, the display module is further configured to: displaying the seismic profile with the location of the reservoir marked in the seismic profile.

In a third aspect, there is provided a terminal comprising a processor and a memory, the memory having stored therein at least one instruction, the at least one instruction being loaded and executed by the processor to implement the method of predicting a reservoir location as described in the first aspect above.

In a fourth aspect, there is provided a computer readable storage medium having stored therein at least one instruction, which is loaded and executed by the processor, to implement the method of predicting a reservoir location as described in the first aspect above.

The technical scheme provided by the embodiment of the invention has the beneficial effects that at least:

when oil and gas move, the oil and gas always move along the direction with small resistance. When the difference (i.e. the difference) between the value of the static rock pressure and the component value is a minimum value, the component value at the position is larger, namely the pressure of the part at the upper side of the fault line to the part at the lower side is larger, which indicates that the opening degree of the fault line at the position is smaller, and the resistance of the oil gas in the direction of the fault line is larger. As a result, hydrocarbons may migrate toward portions on either side of the fault line, thereby forming a reservoir at that location. Therefore, the oil and gas reservoir exists at the position on the fault line corresponding to the minimum value of the predicted difference value. Therefore, when lithology characteristics on two sides of the fault are consistent, the position of the oil and gas reservoir can be predicted through the method provided by the embodiment of the invention. Therefore, the embodiment of the invention can provide a method for judging the position of the fault oil-gas reservoir.

Drawings

In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the description of the embodiments will be briefly introduced below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings based on these drawings without creative efforts.

FIG. 1 is a flow chart of a method of predicting reservoir location provided by an embodiment of the present invention;

FIG. 2 is a schematic diagram of an apparatus for predicting reservoir location according to an embodiment of the present invention;

fig. 3 is a block diagram of a terminal according to an embodiment of the present invention;

FIG. 4 is a schematic structural diagram of a computer device according to an embodiment of the present invention;

FIG. 5 is a cross-sectional view of a seismic source according to an embodiment of the present invention;

fig. 6 is a depth versus pressure graph provided by an embodiment of the present invention.

Detailed Description

In order to make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be described in detail with reference to the accompanying drawings.

Embodiments of the present invention provide a method for predicting a location of a hydrocarbon reservoir, which may be implemented by a computer device. The computer device may be a mobile terminal such as a mobile phone, a tablet computer, a notebook computer, or the like, or a fixed terminal such as a desktop computer, or a server.

The computer device is equipped with an application program for predicting the location of the reservoir, and when oil and gas exploration is needed, the application program can be opened to predict the reservoir.

As shown in fig. 1, the processing flow of the method may include the following steps:

in step 101, a seismic profile of a target area is acquired and a fault line of the seismic profile is determined.

Wherein the seismic profile shows the geological formation of the subsurface of the target area. Fault lines refer to fault lines on a seismic profile.

In practice, after the target area is selected, seismic exploration is performed on the target area to obtain a seismic profile of the target area. And the terminal acquires a seismic section of the target area and adjusts the ratio of the longitudinal depth to the transverse length of the seismic section to 1: 1. And then determining fault lines on the seismic section diagram according to the characteristic of the seismic event mismatching.

Optionally, in order to observe the geological structure of the target region and mark the predicted location of the hydrocarbon reservoir in the seismic profile, the corresponding processing in step 101 is as follows: a seismic profile is displayed.

In implementation, a seismic profile of a target area is acquired, and after the ratio of the longitudinal depth to the transverse length of the seismic profile is adjusted to 1:1, the seismic profile of the target area is displayed. After the fault line on the seismic profile is determined, the fault line is displayed on the seismic profile, as shown in FIG. 5. The part above the fault line is called the upper plate, and the part below the fault line is called the lower plate. Optionally, the fault line may be highlighted, for example, a special color is selected to display the fault line.

In step 102, the statics pressures at a plurality of locations on a fault line of a seismic profile are determined.

Wherein the direction of the lithostatic pressure is vertically downward.

In practice, a sufficient number of points are selected on the fault line and the lithostatic pressure is calculated for the locations represented by these points. Alternatively, one point may be selected at each horizontal distance on the fault line and the static rock pressure may be calculated for the locations represented by these points. The calculation formula of the value of the dead rock pressure is as follows:

P＝ρgh

where P represents the value of the static rock pressure, g represents the gravitational acceleration, h represents the depth, and ρ represents the average density of the upper disk.

g may be taken to be 9.8m/s². When g is 9.8m/s²P is proportional to the depth h, since the average density of the upper disk, represented by P, is also a constant.

Optionally, curve fitting may be performed according to the obtained static rock pressure values at the plurality of positions and the depth values at the positions, and a curve corresponding to the fitted function is displayed. The corresponding processing procedure of step 102 is as follows: and performing curve fitting according to the static rock pressure and the depth value corresponding to each position to obtain a second relation function of the depth value and the static rock pressure on the fault line, and displaying a curve corresponding to the second relation function.

In practice, g is 9.8m/s²Therefore, the curve corresponding to the second relation function is a straight line, and the curve corresponding to the second relation function is displayed in the image with the depth value as the ordinate and the pressure as the abscissa, as shown in fig. 6.

In step 103, a component of the lithostatic pressure in a direction perpendicular to the fault line for each of the plurality of locations is determined.

In implementation, after the statolitic pressures at the positions are determined, the forces of the statolitic pressures are decomposed, and component values of the statolitic pressures at each position in the direction perpendicular to the fault line are obtained.

Optionally, the corresponding processing procedure of step 103 may be as follows: determining an included angle between a tangent line of each of a plurality of positions on a fault line of the seismic profile and a horizontal line; and determining the component of the static rock pressure in the direction perpendicular to the fault line in each position in the plurality of positions based on the angle between the static rock pressure in each position and the tangent line of each position and the horizontal line.

In practice, the calculation formula of the components of the lithostatic pressure is as follows:

P₁＝P·cosα＝ρgh·cosα

wherein, P₁Values for the components are represented, P represents the value of the static rock pressure, g represents the gravitational acceleration, h represents the depth, ρ represents the average density of the upper disk, and α represents the angle of the tangent to the horizontal at each position.

Optionally, curve fitting may be performed according to the obtained component values of the lithostatic pressure at the multiple positions and the depth values of the positions, and a curve corresponding to the fitted function is displayed. The corresponding processing procedure of step 103 may be as follows: and performing curve fitting according to the component and the depth value of the static rock pressure value of each position in the direction vertical to the fault line to obtain a third relation function of the depth value and the component on the fault line, and displaying a curve corresponding to the third relation function.

In practice, the expression of the third relation function is P₁The graph corresponding to the third relational function and the graph corresponding to the second relational function are displayed together in a graph in which the depth value is set as the ordinate and the pressure is set as the abscissa, as shown in fig. 6.

Optionally, in order to intuitively predict the location of the hydrocarbon reservoir, the corresponding processing of step 103 may be as follows: highlighting a portion between a curve corresponding to the second relation function and a curve corresponding to the third relation function.

In an implementation, a portion between the curve corresponding to the second relation function and the curve corresponding to the third relation function may be filled with black color to be highlighted, as shown in fig. 6. The location of the reservoir can be predicted approximately from fig. 6, predicting the location corresponding to the bottleneck portion of the black portion between the two lines as the location of the reservoir. The bottleneck portion of the black portion means that the black range width at that point is a minimum value of the black range width.

In step 104, a difference between the statolitic pressure at each location and a component of the statolitic pressure in a direction perpendicular to the fault line is determined.

In implementation, the component values of the static rock pressure value corresponding to each position and the static rock pressure in the direction perpendicular to the fault line are subtracted to obtain a difference value. Each position corresponds to a difference.

In step 105, curve fitting is performed according to the difference and the depth value corresponding to each position, so as to obtain a first relation function between the depth value and the difference on the fault line.

In step 106, the minimum value of the difference in the first relation function is determined, and the location of the reservoir is predicted according to the location on the fault line corresponding to the minimum value.

The position on the fault line corresponding to the minimum value of the difference in the first relation function is the position where the hydrocarbon reservoir is likely to exist, namely the predicted hydrocarbon reservoir position.

Optionally, the predicted depth of the hydrocarbon reservoir may be marked in a map in which the second relation function and the third relation function exist, and the corresponding processing in step 106 is as follows: and marking and displaying the depth value corresponding to the minimum value.

In practice, the depth of the predicted reservoir location is derived from the location corresponding to the minimum of the difference in the first relationship function and marked in the graph where the second relationship function and the third relationship function exist, as shown in fig. 6.

Alternatively, the location of the predicted reservoir may be marked in the seismic profile, and the corresponding process of step 106 is as follows: the location of the reservoir is marked in the seismic profile.

In implementation, the depth of the predicted reservoir location is derived from the location corresponding to the minimum of the difference in the first relationship function, and the location corresponding to that depth is marked on the fault line of the seismic profile, as shown in fig. 5.

Based on the same technical concept, an embodiment of the present invention further provides an apparatus for predicting a location of a hydrocarbon reservoir, which may be a computer device in the foregoing embodiment, as shown in fig. 2, and the apparatus includes:

an obtaining module 201, configured to obtain a seismic profile of a target area, and determine a fault line of the seismic profile;

a determining module 202, configured to determine a statics pressure at a plurality of locations on a fault line of the seismic profile, determine a component of the statics pressure at each of the plurality of locations in a direction perpendicular to the fault line, and determine a difference between the statics pressure at each of the locations and the component of the statics pressure in the direction perpendicular to the fault line;

the fitting module 203 is configured to perform curve fitting according to the difference and the depth value corresponding to each position to obtain a first relation function between the depth value and the difference value on the fault line;

and the predicting module 204 is configured to determine a minimum value of the difference in the first relation function, and predict a location of the hydrocarbon reservoir according to a location on the fault line corresponding to the minimum value.

Optionally, the determining module 202 is configured to:

Optionally, the apparatus further comprises:

and the display module 205 is configured to perform curve fitting according to the static rock pressure and the depth value corresponding to each position, obtain a second relation function between the depth value and the static rock pressure on the fault line, display a curve corresponding to the second relation function, perform curve fitting according to the component and the depth value of the static rock pressure in each position in the direction perpendicular to the fault line, obtain a third relation function between the depth value and the component on the fault line, and display a curve corresponding to the third relation function.

Optionally, the display module 205 is further configured to:

and marking and displaying the depth value corresponding to the minimum value.

Optionally, the display module 205 is further configured to:

displaying the seismic profile with the location of the reservoir marked in the seismic profile.

With regard to the apparatus in the above-described embodiment, the specific manner in which each module performs the operation has been described in detail in the embodiment related to the method, and will not be elaborated here.

It should be noted that: in the device for predicting a reservoir location according to the above embodiment, when the reservoir location is predicted, only the division of the above function modules is used for illustration, and in practical application, the function distribution may be completed by different function modules according to needs, that is, the internal structure of the apparatus is divided into different function modules, so as to complete all or part of the functions described above. In addition, the device for predicting the position of the oil and gas reservoir provided by the embodiment and the method for predicting the position of the oil and gas reservoir belong to the same concept, and the specific implementation process is detailed in the method embodiment and is not repeated herein.

Fig. 3 is a block diagram of a terminal according to an embodiment of the present invention. The terminal 300 may be a portable mobile terminal such as: smart phones, tablet computers. The terminal 300 may also be referred to by other names such as user equipment, portable terminal, etc.

Generally, the terminal 300 includes: a processor 301 and a memory 302.

The processor 301 may include one or more processing cores, such as a 4-core processor, and so on. The processor 301 may be implemented in at least one hardware form of a DSP (Digital Signal Processing), an FPGA (Field-Programmable Gate Array), and a PLA (Programmable Logic Array). The processor 301 may also include a main processor and a coprocessor, where the main processor is a processor for processing data in an awake state, and is also called a Central Processing Unit (CPU); a coprocessor is a low power processor for processing data in a standby state. In some embodiments, the processor 301 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content required to be displayed on the display screen. In some embodiments, the processor 301 may further include an AI (Artificial Intelligence) processor for processing computing operations related to machine learning.

Memory 302 may include one or more computer-readable storage media, which may be tangible and non-transitory. Memory 302 may also include high speed random access memory, as well as non-volatile memory, such as one or more magnetic disk storage devices, flash memory storage devices. In some embodiments, a non-transitory computer readable storage medium in memory 302 is used to store at least one instruction for execution by processor 301 to implement the methods of predicting reservoir location provided herein.

In some embodiments, the terminal 300 may further include: a peripheral interface 303 and at least one peripheral. Specifically, the peripheral device includes: at least one of radio frequency circuitry 304, touch display screen 305, camera 306, audio circuitry 307, positioning components 308, and power supply 309.

The peripheral interface 303 may be used to connect at least one peripheral related to I/O (Input/Output) to the processor 301 and the memory 302. In some embodiments, processor 301, memory 302, and peripheral interface 303 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 301, the memory 302 and the peripheral interface 303 may be implemented on a separate chip or circuit board, which is not limited by the embodiment.

The Radio Frequency circuit 304 is used for receiving and transmitting RF (Radio Frequency) signals, also called electromagnetic signals. The radio frequency circuitry 304 communicates with communication networks and other communication devices via electromagnetic signals. The rf circuit 304 converts an electrical signal into an electromagnetic signal to transmit, or converts a received electromagnetic signal into an electrical signal. Optionally, the radio frequency circuit 304 comprises: an antenna system, an RF transceiver, one or more amplifiers, a tuner, an oscillator, a digital signal processor, a codec chipset, a subscriber identity module card, and so forth. The radio frequency circuitry 304 may communicate with other terminals via at least one wireless communication protocol. The wireless communication protocols include, but are not limited to: the world wide web, metropolitan area networks, intranets, generations of mobile communication networks (2G, 3G, 4G, and 5G), Wireless local area networks, and/or WiFi (Wireless Fidelity) networks. In some embodiments, the rf circuit 304 may further include NFC (Near Field Communication) related circuits, which are not limited in this application.

The touch display screen 305 is used to display a UI (User Interface). The UI may include graphics, text, icons, video, and any combination thereof. Touch display screen 305 also has the ability to capture touch signals on or over the surface of touch display screen 305. The touch signal may be input to the processor 301 as a control signal for processing. The touch screen display 305 is used to provide virtual buttons and/or a virtual keyboard, also referred to as soft buttons and/or a soft keyboard. In some embodiments, the touch display screen 305 may be one, providing the front panel of the terminal 300; in other embodiments, the touch display screen 305 may be at least two, respectively disposed on different surfaces of the terminal 300 or in a folded design; in still other embodiments, the touch display 305 may be a flexible display disposed on a curved surface or on a folded surface of the terminal 300. Even more, the touch screen display 305 may be arranged in a non-rectangular irregular pattern, i.e., a shaped screen. The touch screen 305 may be made of LCD (liquid crystal Display), OLED (Organic Light-Emitting Diode), and the like.

The camera assembly 306 is used to capture images or video. Optionally, camera assembly 306 includes a front camera and a rear camera. Generally, a front camera is used for realizing video call or self-shooting, and a rear camera is used for realizing shooting of pictures or videos. In some embodiments, the number of the rear cameras is at least two, and each of the rear cameras is any one of a main camera, a depth-of-field camera and a wide-angle camera, so that the main camera and the depth-of-field camera are fused to realize a background blurring function, and the main camera and the wide-angle camera are fused to realize a panoramic shooting function and a VR (Virtual Reality) shooting function. In some embodiments, camera assembly 306 may also include a flash. The flash lamp can be a monochrome temperature flash lamp or a bicolor temperature flash lamp. The double-color-temperature flash lamp is a combination of a warm-light flash lamp and a cold-light flash lamp, and can be used for light compensation at different color temperatures.

Audio circuit 307 is used to provide an audio interface between the user and terminal 300. Audio circuitry 307 may include a microphone and a speaker. The microphone is used for collecting sound waves of a user and the environment, converting the sound waves into electric signals, and inputting the electric signals to the processor 301 for processing or inputting the electric signals to the radio frequency circuit 304 to realize voice communication. The microphones may be provided in plural numbers, respectively, at different portions of the terminal 300 for the purpose of stereo sound collection or noise reduction. The microphone may also be an array microphone or an omni-directional pick-up microphone. The speaker is used to convert electrical signals from the processor 301 or the radio frequency circuitry 304 into sound waves. The loudspeaker can be a traditional film loudspeaker or a piezoelectric ceramic loudspeaker. When the speaker is a piezoelectric ceramic speaker, the speaker can be used for purposes such as converting an electric signal into a sound wave audible to a human being, or converting an electric signal into a sound wave inaudible to a human being to measure a distance. In some embodiments, audio circuitry 307 may also include a headphone jack.

The positioning component 308 is used to locate the current geographic location of the terminal 300 to implement navigation or LBS (location based Service). The positioning component 308 may be a positioning component based on the GPS (global positioning System) in the united states, the beidou System in china, or the galileo System in russia.

The power supply 309 is used to supply power to the various components in the terminal 300. The power source 309 may be alternating current, direct current, disposable batteries, or rechargeable batteries. When the power source 309 includes a rechargeable battery, the rechargeable battery may be a wired rechargeable battery or a wireless rechargeable battery. The wired rechargeable battery is a battery charged through a wired line, and the wireless rechargeable battery is a battery charged through a wireless coil. The rechargeable battery may also be used to support fast charge technology.

In some embodiments, the terminal 300 also includes one or more sensors 310. The one or more sensors 310 include, but are not limited to: acceleration sensor 311, gyro sensor 312, pressure sensor 313, fingerprint sensor 314, optical sensor 315, and proximity sensor 316.

The acceleration sensor 311 may detect the magnitude of acceleration in three coordinate axes of a coordinate system established with the terminal 300. For example, the acceleration sensor 311 may be used to detect components of the gravitational acceleration in three coordinate axes. The processor 301 may control the touch display screen 305 to display the user interface in a landscape view or a portrait view according to the gravitational acceleration signal collected by the acceleration sensor 311. The acceleration sensor 311 may also be used for acquisition of motion data of a game or a user.

The gyro sensor 312 may detect a body direction and a rotation angle of the terminal 300, and the gyro sensor 312 may cooperate with the acceleration sensor 311 to acquire a 3D motion of the user on the terminal 300. The processor 301 may implement the following functions according to the data collected by the gyro sensor 312: motion sensing (such as changing the UI according to a user's tilting operation), image stabilization at the time of photographing, game control, and inertial navigation.

The pressure sensor 313 may be disposed on a side bezel of the terminal 300 and/or an underlying layer of the touch display screen 305. When the pressure sensor 313 is disposed at the side frame of the terminal 300, a user's grip signal of the terminal 300 can be detected, and left-right hand recognition or shortcut operation can be performed according to the grip signal. When the pressure sensor 313 is disposed at the lower layer of the touch display screen 305, the operability control on the UI interface can be controlled according to the pressure operation of the user on the touch display screen 305. The operability control comprises at least one of a button control, a scroll bar control, an icon control and a menu control.

The fingerprint sensor 314 is used for collecting a fingerprint of a user to identify the identity of the user according to the collected fingerprint. Upon identifying that the user's identity is a trusted identity, processor 301 authorizes the user to perform relevant sensitive operations including unlocking the screen, viewing encrypted information, downloading software, paying, and changing settings, etc. The fingerprint sensor 314 may be disposed on the front, back, or side of the terminal 300. When a physical button or a vendor Logo is provided on the terminal 300, the fingerprint sensor 314 may be integrated with the physical button or the vendor Logo.

The optical sensor 315 is used to collect the ambient light intensity. In one embodiment, the processor 301 may control the display brightness of the touch screen display 305 based on the ambient light intensity collected by the optical sensor 315. Specifically, when the ambient light intensity is high, the display brightness of the touch display screen 305 is increased; when the ambient light intensity is low, the display brightness of the touch display screen 305 is turned down. In another embodiment, the processor 301 may also dynamically adjust the shooting parameters of the camera head assembly 306 according to the ambient light intensity collected by the optical sensor 315.

A proximity sensor 316, also known as a distance sensor, is typically provided on the front face of the terminal 300. The proximity sensor 316 is used to collect the distance between the user and the front surface of the terminal 300. In one embodiment, when the proximity sensor 316 detects that the distance between the user and the front surface of the terminal 300 gradually decreases, the processor 301 controls the touch display screen 305 to switch from the bright screen state to the dark screen state; when the proximity sensor 316 detects that the distance between the user and the front surface of the terminal 300 gradually becomes larger, the processor 301 controls the touch display screen 305 to switch from the breath screen state to the bright screen state.

Those skilled in the art will appreciate that the configuration shown in fig. 3 is not intended to be limiting of terminal 300 and may include more or fewer components than those shown, or some components may be combined, or a different arrangement of components may be used.

In an exemplary embodiment, a computer readable storage medium having at least one instruction stored therein is provided, the at least one instruction being loaded and executed by a processor to implement the method of predicting reservoir location in the above embodiments. For example, the computer readable storage medium may be a ROM, a Random Access Memory (RAM), a CD-ROM, a magnetic tape, a floppy disk, an optical data storage device, and the like.

Fig. 4 is a schematic structural diagram of a computer device 400 according to an embodiment of the present invention, where the computer device 400 may generate a relatively large difference due to different configurations or performances, and may include one or more processors (CPUs) 401 and one or more memories 402, where the memory 402 stores at least one instruction, and the at least one instruction is loaded and executed by the processor 401 to implement the method for predicting a hydrocarbon reservoir location.

It will be understood by those skilled in the art that all or part of the steps for implementing the above embodiments may be implemented by hardware, or may be implemented by a program instructing relevant hardware, where the program may be stored in a computer-readable storage medium, and the above-mentioned storage medium may be a read-only memory, a magnetic disk or an optical disk, etc.

The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.

Claims

1. A method of predicting a location of a hydrocarbon reservoir, the method comprising:

2. The method of claim 1, wherein the determining a component of the lithostatic pressure at each of the plurality of locations in a direction perpendicular to the fault line comprises:

3. The method of claim 1, wherein after determining the lithostatic pressure at the plurality of locations on the fault line of the seismic profile, further comprising:

after the determining a component of the lithostatic pressure in a direction perpendicular to the fault line for each of the plurality of locations, further comprising:

4. The method according to claim 3, wherein curve fitting is performed according to the component of the static rock pressure at each position in the direction perpendicular to the fault line and the depth value, so as to obtain a third relation function of the depth value and the component on the fault line, and after a curve corresponding to the third relation function is displayed, the method further comprises:

5. The method of claim 3, wherein after determining a minimum value of the difference in the relationship function and predicting the location of the reservoir based on the location on the fault line corresponding to the minimum value, further comprising:

and marking and displaying the depth value corresponding to the minimum value.

6. The method of claim 1, wherein the obtaining a seismic profile of the target area, after determining the fault line of the seismic profile, further comprises:

displaying the seismic profile;

the location of the reservoir is marked in the seismic profile.

7. An apparatus for predicting a location of a hydrocarbon reservoir, the apparatus comprising:

8. The apparatus of claim 7, wherein the determining module is configured to:

9. The apparatus of claim 7, further comprising:

10. The apparatus of claim 9, wherein the display module is further configured to:

11. The apparatus of claim 9, wherein the display module is further configured to:

and marking and displaying the depth value corresponding to the minimum value.

12. The apparatus of claim 7, further comprising a display module to: displaying the seismic profile with the location of the reservoir marked in the seismic profile.

13. A terminal comprising a processor and a memory, the memory having stored therein at least one instruction, the at least one instruction being loaded and executed by the processor to implement the method of predicting a hydrocarbon reservoir as claimed in any one of claims 1 to 6.

14. A computer readable storage medium having stored therein at least one instruction which is loaded and executed by a processor to implement the method of predicting hydrocarbon reservoirs of any one of claims 1 to 6.