CN117520720A

CN117520720A - Formation pressure calculation method and device, electronic equipment and medium

Info

Publication number: CN117520720A
Application number: CN202210905544.7A
Authority: CN
Inventors: 王磊; 张金龙; 张祯祥; 李基伟; 柯珂; 邱康; 张文平; 李莅临; 张辉; 熊振宇
Original assignee: SHANGHAI OCEAN OIL GAS BRANCH OF SINOPEC; China Petroleum and Chemical Corp; Sinopec Petroleum Engineering Technology Research Institute Co Ltd
Current assignee: SHANGHAI OCEAN OIL GAS BRANCH OF SINOPEC; China Petroleum and Chemical Corp; Sinopec Petroleum Engineering Technology Research Institute Co Ltd
Priority date: 2022-07-29
Filing date: 2022-07-29
Publication date: 2024-02-06

Abstract

The disclosure relates to the technical field of formation pressure calculation, and provides a formation pressure calculation method, a device, electronic equipment and a medium. The method comprises the following steps: acquiring logging data of a target abnormal high-pressure stratum at a target depth in the drilling process; judging a causative mechanism of the target abnormal high-pressure stratum based on the logging data, and calculating the overburden pressure; generating a vertical effective stress based on the causal mechanism and the logging data; a target formation pressure is calculated based on the overburden pressure and the vertical effective stress. According to the embodiment of the disclosure, through the steps, the prediction accuracy of the formation pressure can be greatly improved.

Description

Formation pressure calculation method and device, electronic equipment and medium

Technical Field

The disclosure relates to the technical field of formation pressure calculation, in particular to a formation pressure calculation method, a device, electronic equipment and a medium.

Background

The accurate calculation of formation pressure is the ballast of the safety well. Since the 60 s of the last century, the petroleum drilling field has gradually formed a series of formation pressure calculation methods. Analysis from computational principles can be broadly divided into three categories: the first method is to establish an intersection plate according to the difference value of certain petrophysical parameters deviating from the normal trend and the formation pore pressure, so as to directly determine the formation pore pressure at different depths of a target area. The method belongs to an empirical method, and the calculation errors in different areas are larger. The second type of method is to establish a normal compaction trend line in the normal section using the variation of various parameters with the depth of the well, and then estimate the formation pressure based on the degree to which the measured value deviates from the trend line. The third method is to directly establish a function equation of the sound wave velocity and the rock effective stress without establishing a normal compaction trend line, and then calculate the formation pressure by using the effective stress principle.

At present, the mainstream method for calculating the formation pressure considers the formation abnormal high pressure mechanism as a loading mechanism, and the formation abnormal high pressure causes are various due to the complex geological environment. The existing stratum pressure calculation method considering the unloading mechanism only comprises a Bowers method (a method for judging the factors of the undercompaction and the fluid expansion based on the relation between the speed, the density, the resistivity and the depth, which is proposed by Bowers in 2002), and only considers the relation between the effective stress of rock and the sonic wave velocity of the rock, and does not consider the influence of factors such as lithology, the porosity of the rock and the like on the sonic wave velocity of the rock, so that the accuracy is lower.

Disclosure of Invention

In view of the above, the embodiments of the present disclosure provide a formation pressure calculation method, apparatus, electronic device, and medium, so as to solve the problem in the prior art that the influence of factors such as lithology, rock porosity, etc. on the acoustic wave velocity of rock is not considered, thus resulting in lower accuracy.

In a first aspect of an embodiment of the present disclosure, there is provided a formation pressure calculation method, including:

acquiring logging data of a target abnormal high-pressure stratum at a target depth in the drilling process;

judging a causative mechanism of the target abnormal high-pressure stratum based on the logging data, and calculating the overburden pressure;

Generating a vertical effective stress based on the causal mechanism and the logging data;

a target formation pressure is calculated based on the overburden pressure and the vertical effective stress.

In some embodiments, the determining a causative mechanism of a target abnormally-high pressure formation based on the logging data includes:

generating an intersection graph taking a rock density value as an abscissa and a shale acoustic wave velocity value as an ordinate based on the shale acoustic wave velocity curve and the rock density curve in the logging data;

judging a causative mechanism of the target abnormal high-pressure stratum based on the slope of the intersection graph;

if the slope of the intersection graph is not greater than a preset first threshold value, determining that the cause mechanism is a loading mechanism;

and if the slope of the intersection graph is not smaller than a preset second threshold value, determining that the cause mechanism is an unloading mechanism.

In some embodiments, the generating vertical effective stress based on the causal mechanism and the logging information comprises:

and when the causative mechanism is a loading mechanism, acquiring a rock porosity value, a rock shale content value and a rock longitudinal wave velocity value of the logging data at the target depth, and generating the vertical effective stress by combining a preset loading mechanism equation, wherein the loading mechanism equation is used for representing a functional relation between the rock longitudinal wave velocity and the vertical effective stress, the rock porosity and the rock shale content of the rock.

In some embodiments, the loading mechanism equation includes:

wherein V represents the rock longitudinal wave velocity value, sigma _ev Represents the vertical effective stress value of the rock, phi represents the porosity value of the rock, V _sh Representing the rock mass content values, A, B, C, D, E are all constant coefficients.

when the cause mechanism is an unloading mechanism, acquiring a starting point of the intersection graph corresponding to the target depth;

acquiring the maximum sonic wave velocity and the maximum vertical effective stress of the unloading layer section rock corresponding to the starting point;

and generating the vertical effective stress by combining a preset unloading mechanism equation based on the rock longitudinal wave velocity value, the rock shale content value and the rock longitudinal wave velocity value at the target depth in the logging data and the maximum acoustic wave velocity and the maximum vertical effective stress, wherein the unloading mechanism equation is used for representing the functional relationship between the rock longitudinal wave velocity and the maximum acoustic wave velocity of the unloading interval rock, the vertical effective stress value of the rock, the maximum vertical effective stress of the unloading interval rock, the rock porosity value and the rock shale content value.

In some embodiments, the offload mechanism equation is:

wherein V represents the wave velocity of rock longitudinal wave, V _m Representing the maximum sonic velocity of the unloaded interval rock; sigma (sigma) _ev Representing the vertical effective stress value of rock, sigma _m Representing the maximum vertical effective stress of the unloaded interval rock, phi representing the rock porosity value; v (V) _sh The rock mass content values are represented, a ', B', C ', D' being constant coefficients.

In some embodiments, calculating overburden pressure based on the logging data includes:

and calculating an overburden pressure value based on the sonic velocity value, the rock density value and the mud line threshold in the logging data.

In some embodiments, the calculating the overburden pressure value based on the sonic velocity value, the rock density value, and the mud line threshold in the well log data includes:

when the depth of the abnormal high-pressure interval mudstone is larger than the mudline threshold value, calculating overburden pressure based on a preset Power law calculation formula, and generating an overburden pressure curve;

and when the depth of the mud rock of the abnormal high-pressure interval is not greater than the mud line threshold value, calculating overburden pressure based on a preset Gardner model, and generating the overburden pressure curve.

In a second aspect of embodiments of the present disclosure, there is provided a formation pressure calculation apparatus comprising:

the acquisition module is used for acquiring logging information of the target abnormal high-pressure stratum at the target depth in the drilling process;

the judging module is used for judging the causative mechanism of the target abnormal high-pressure stratum based on the logging data and calculating the overlying strata pressure;

the generation module is used for generating vertical effective stress based on the cause mechanism and the logging data;

and the calculation module is used for calculating target formation pressure based on the overburden pressure and the vertical effective stress.

In some embodiments, the loading mechanism equation includes:

And generating the vertical effective stress by combining a preset unloading mechanism equation based on the rock longitudinal wave velocity value, the rock shale content value and the rock longitudinal wave velocity value at the target depth in the logging data, and the maximum acoustic wave velocity and the maximum vertical effective stress, wherein the unloading mechanism equation is used for representing a functional relation between the rock longitudinal wave velocity and the maximum acoustic wave velocity of the unloading interval rock, the vertical effective stress value of the rock, the maximum vertical effective stress of the unloading interval rock, the rock porosity value and the rock shale content value.

In some embodiments, the offload mechanism equation is:

In a third aspect of the disclosed embodiments, there is provided an electronic device comprising a memory, a processor and a computer program stored in the memory and executable on the processor, the steps implemented by the processor when executing the computer program comprising:

In some embodiments, the loading mechanism equation includes:

In some embodiments, the offload mechanism equation is:

In a fourth aspect of the disclosed embodiments, there is provided a computer-readable storage medium storing a computer program which, when executed by a processor, performs steps comprising:

In some embodiments, the loading mechanism equation includes:

In some embodiments, the offload mechanism equation is:

Advantageous effects

Compared with the prior art, the beneficial effects of the embodiment of the disclosure at least comprise: acquiring logging data of mud rock of an abnormal high-pressure interval, and generating an overburden pressure curve based on the logging data; determining a cause mechanism type, and generating vertical effective stress based on an equation corresponding to the cause mechanism type and the logging data; and calculating the target formation pressure based on the overburden pressure and the vertical effective stress, so that the prediction accuracy of the formation pressure can be greatly improved.

Drawings

In order to more clearly illustrate the technical solutions of the embodiments of the present disclosure, the drawings that are required for the embodiments or the description of the prior art will be briefly introduced below, and it is obvious that the drawings in the following description are only the embodiments, and other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.

FIG. 1 is a schematic diagram of one scenario of a formation pressure calculation method provided in accordance with an embodiment of the present disclosure;

FIG. 2 is a flow chart of a second embodiment of a formation pressure calculation method provided in accordance with an embodiment of the present disclosure;

FIG. 3 is an intersection graph of a shale acoustic wave velocity value as an ordinate with a rock density value as an abscissa, according to a formation pressure calculation method provided by an embodiment of the present disclosure;

FIG. 4 is a flow chart of an embodiment three of another formation pressure calculation method provided in accordance with an embodiment of the present disclosure;

FIG. 5 is a simplified schematic diagram of a formation pressure calculation apparatus provided in accordance with an embodiment of the disclosure;

fig. 6 is a schematic diagram of an electronic device provided according to an embodiment of the present disclosure.

Detailed Description

Embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. While certain embodiments of the present disclosure are shown in the drawings, it should be understood that the present disclosure may be embodied in various forms and should not be construed as limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete. It should be understood that the drawings and embodiments of the present disclosure are for illustration purposes only and are not intended to limit the scope of the present disclosure.

It should be further noted that, for convenience of description, only a portion relevant to the present disclosure is shown in the drawings. Embodiments of the present disclosure and features of embodiments may be combined with each other without conflict.

It should be noted that the terms "first," "second," and the like in this disclosure are merely used to distinguish between different systems, devices, modules, or units and are not intended to limit the order or interdependence of functions performed by such systems, devices, modules, or units.

It should be noted that references to "one", "a plurality" and "a plurality" in this disclosure are intended to be illustrative rather than limiting, and those of ordinary skill in the art will appreciate that "one or more" is intended to be understood as "one or more" unless the context clearly indicates otherwise.

The names of messages or information interacted between the various devices in the embodiments of the present disclosure are for illustrative purposes only and are not intended to limit the scope of such messages or information.

The present disclosure will be described in detail below with reference to the accompanying drawings in conjunction with embodiments.

Embodiment one:

fig. 1 is a schematic diagram of an application scenario of a formation pressure calculation method according to a first embodiment of the present disclosure.

In the application scenario of fig. 1, first, the computing device 101 may acquire logging data 102 of a target abnormally high pressure formation at a target depth during a drilling process.

Second, the computing device 101 may determine the causative mechanism 103 of the target abnormally-high pressure formation based on the log 102, and calculate overburden pressure 104.

Again, the computing device 101 may generate a vertical effective stress 105 based on the causal mechanism 103 and the logging data 102.

Finally, computing device 101 may calculate a target formation pressure 106 based on the overburden pressure 104 and the vertical effective stress 105.

The computing device 101 may be hardware or software. When the computing device is hardware, the computing device may be implemented as a distributed cluster formed by a plurality of servers or terminal devices, or may be implemented as a single server or a single terminal device. When the computing device is embodied as software, it may be installed in the hardware devices listed above. It may be implemented as a plurality of software or software modules, for example, for providing distributed services, or as a single software or software module. The present invention is not particularly limited herein.

It should be understood that the number of computing devices in fig. 1 is merely illustrative. There may be any number of computing devices, as desired for an implementation.

Embodiment two:

with continued reference to fig. 2, a flow 200 of a second embodiment of a formation pressure calculation method according to the present disclosure is shown. The method may be performed by the computing device 101 in fig. 1. The method for calculating the formation pressure comprises the following steps:

step 201, acquiring logging information of a target abnormally high pressure stratum at a target depth in a drilling process.

In some alternative implementations, the execution body of the formation pressure calculation method (such as the calculation device 101 shown in fig. 1) may connect to the target device via a wired connection or a wireless connection, and then acquire logging data of the target abnormally-high pressure formation at the target depth during the drilling process.

Because the strata of the formation are formed layer by layer, different situations of geologic depositions can lead to the formation of abnormally high pressures. The target abnormally high pressure formation may indicate one of the formations where an abnormally high pressure region is present. In general, a pressure value 1.2 times or more greater than the normal high pressure may be referred to as an abnormally high pressure. As an example, if the pressure of the normal high pressure is a, the pressure of the abnormal high pressure may be 1.5A or 2A, or the like. The target depth may refer to specific depth data. The depth data may be surface-based relative depth data. Logging data can refer to various data related to logging, such as rock density data, sonic time difference data, shale sonic wave velocity and the like, acquired in the logging process. The above data are all common data in the prior art, and are not described in detail herein.

It should be noted that the wireless connection may include, but is not limited to, 3G/4G/5G connection, wiFi connection, bluetooth connection, wiMAX connection, zigbee connection, UWB (ultra wideband) connection, and other now known or later developed wireless connection.

Step 202, judging the causative mechanism of the target abnormal high-pressure stratum based on the logging data, and calculating the overburden pressure.

In some embodiments, the executing entity may determine a causative mechanism of the target abnormally-high pressure formation based on the logging data, and calculate overburden pressure. The causative mechanism of the abnormally high pressure formation may refer to a mechanism of forming the abnormally high pressure formation, which is generalized in the prior art.

In some embodiments, the causative mechanisms may include a loading mechanism and an unloading mechanism. When judging that the cause mechanism is a loading mechanism or an unloading mechanism, the method can judge by the following steps:

in the first step, the executing body may generate an intersection graph with the rock density value as an abscissa and the shale acoustic wave velocity value as an ordinate based on the shale acoustic wave velocity curve and the rock density curve in the logging data. The shale acoustic wave velocity may refer to the velocity of acoustic wave propagation in shale. Rock density may refer to density data of rock in a target formation. Correspondingly, the shale acoustic wave velocity curve and the rock density curve can respectively represent curves formed by data of the shale acoustic wave velocity and the rock density at different depths. It should be noted that, the shale acoustic wave velocity curve and the rock density curve are common data in the field, and are not described herein.

And a second step, if the slope of the intersection is not greater than a preset first threshold, the execution body may determine that the cause mechanism is a loading mechanism. The first threshold may refer to a preset curve slope limit value for determining whether the loading mechanism is. When the slope of the intersection graph is not greater than the first threshold, the cause mechanism may be determined to be a loading mechanism. The loading mechanism may also be referred to as a undercompact mechanism. In the formation, the distribution of fluids is also layer by layer. When the pressure coefficient is common high pressure, the fluid below the stratum is communicated with the outside. When the internal pressure is too high, the fluid may be discharged to the outside. If rapid deposition occurs at this time, fluid is not discharged in time, resulting in a slow fluid discharge rate in the pores, which may lead to some dense mud or rock formation, resulting in abnormally high pressures, which emotion may be generally referred to as a loading mechanism. Most abnormally high voltages are also the causative mechanism.

And thirdly, if the slope of the intersection is not smaller than a preset second threshold, the execution body can determine that the cause mechanism is an unloading mechanism. The second threshold may refer to a preset curve slope limit value for determining whether the unloading mechanism is present. The unloading mechanism is more in cause, such as abnormal high pressure caused by the fact that fluid and gas cannot be discharged in time, and the loading mechanism and the unloading mechanism are both in the prior art and are not described in detail herein. It is noted that the second threshold is greater than the first threshold.

With continued reference to fig. 3, an intersection graph is shown with the rock density values as the abscissa and the shale sonic wave velocity values as the ordinate. Obviously, the slope of the curve corresponding to the loading mechanism is smaller, and the slope corresponding to the unloading mechanism is larger. When the curve is not greater than the first threshold, such as the curve on the left in FIG. 3, then the cause mechanism may be determined to be the load mechanism. When the curve is not less than the second threshold, such as the curve on the right in fig. 3, then the causative mechanism may be determined to be the offloading mechanism.

Overburden pressure may refer to the pressure created by the sum of the matrix mass of the overburden and the mass of the fluid (oil, gas, water) in the overburden pores.

In some optional implementations of some embodiments, the executing entity may calculate the overburden pressure value based on the sonic velocity value, the rock density value, and the mud line threshold in the well log data by:

the first step: when the depth of the mudstone of the abnormally-high pressure interval is greater than the mudline threshold, the execution body may calculate an overburden pressure based on a preset Power law (Power distribution, power-law Distributions) calculation formula, and generate the overburden pressure curve.

As an example, the Power law calculation may be:

ρ＝ρ ₀ +Az ^B

P ₀ current depth gravitational acceleration =ρ ×

Wherein: p (P) ₀ For overburden pressure, ρ may refer to the density of the target locations, ρ ₀ May refer to the formation density at the mud line, and z may refer to the formation depth below the mud line, A, B being a constant coefficient.

And a second step of: when the depth of the abnormally-high pressure interval mudstone is not greater than the mudline threshold, the execution body may calculate an overburden pressure based on a preset Gardner model (Gardner equation), and generate the overburden pressure curve.

As an example, the Gardner model may be:

ρ＝A(V _int ) ^B

P ₀ current depth gravitational acceleration =ρ ×

In the middle of：P ₀ For overburden pressure, ρ may refer to the density of the target locations, V _int For the sonic velocity, A, B is a constant coefficient.

Mud lines, also known as mud belts, may refer to the boundaries between silt and clay and gravel and sand grade material deposition areas in continental shelf areas. The mudline threshold may refer to a depth-related limit value set based on the mudline.

Step 203, generating vertical effective stress based on the cause mechanism and the logging data.

In some embodiments, the execution body may generate the vertical effective stress through the causal mechanism and the logging information based on:

First case: when the cause mechanism is a loading mechanism, the executing body may acquire a rock porosity value, a rock shale content value, and a rock longitudinal wave velocity value at the target depth in the logging data, and generate the vertical effective stress in combination with a preset loading mechanism equation, where the loading mechanism equation is used to characterize a functional relationship between the rock longitudinal wave velocity and the vertical effective stress, the rock porosity, and the rock shale content of the rock, and the loading mechanism equation includes:

wherein V represents the rock longitudinal wave velocity value, sigma _ev Represents the vertical effective stress value of the rock, phi represents the porosity value of the rock, V _sh Representing the rock shale content values, A, B, C, D, E are all constant coefficients, and the rock porosity values may refer to data related to the porosity of the rock. The petrolatum content value may refer to data related to the content of petrolatum. The rock longitudinal wave velocity value may refer to the propagation velocity of the longitudinal wave of the acoustic wave in the rock. Effective stress may refer to the average normal stress transmitted through the inter-granular contact surface of the soil under load, also known as inter-granular stress. The vertical effective stress may refer to an effective stress in a vertical direction. Loading mechanism equation set for the present disclosure for calculating rock vertical effective Equation of force.

Second case: when the cause mechanism is an unload mechanism, the execution body may first obtain a starting point of the intersection map corresponding to the target depth. The starting point may refer to the starting point of the curve corresponding to the unloading mechanism in the intersection graph.

And then, the execution main body can acquire the maximum sonic wave velocity and the maximum vertical effective stress of the unloading interval rock corresponding to the starting point.

Finally, the executing body may generate the vertical effective stress based on the rock longitudinal wave velocity value, the rock mud content value, the rock longitudinal wave velocity value, the maximum acoustic wave velocity and the maximum vertical effective stress in the logging data and in combination with a preset unloading mechanism equation, where the unloading mechanism equation is used to represent a functional relationship between the rock longitudinal wave velocity and the maximum acoustic wave velocity of the unloaded interval rock, the vertical effective stress value of the rock, the maximum vertical effective stress of the unloaded interval rock, the rock porosity value, and the rock mud content value, and the unloading mechanism equation is:

wherein V represents the wave velocity of rock longitudinal wave, V _m Representing the maximum sonic velocity of the unloaded interval rock; sigma (sigma) _ev Representing the vertical effective stress value of rock, sigma _m Representing the maximum vertical effective stress of the unloaded interval rock, phi representing the rock porosity value; v (V) _sh The rock mass content values are represented, a ', B', C ', D' being constant coefficients. Under an unloading mechanism, the greater the depth, the smaller the sound wave velocity and the smaller the vertical effective stress, so the maximum sound wave velocity can refer to the corresponding sound wave velocity at the starting point; the maximum vertical effective stress may refer to the corresponding vertical effective stress at the starting point.

Step 204, calculating a target formation pressure based on the overburden pressure and the vertical effective stress.

In some embodiments, the above-described executing body may calculate the target formation pressure based on the overburden pressure and the vertical effective stress by the following calculation:

P _P ＝(P ₀ -σ _ev )/α

wherein: p (P) _p Is the formation pore pressure, P ₀ For overburden pressure, sigma _ev For the vertical effective stress of the rock, α is the effective stress coefficient (constant coefficient) of the formation rock, and the target formation pressure may refer to pressure data of the target formation calculated.

According to the embodiment, the characteristics of formation abnormal high pressure causes are combined, function equations of the acoustic wave velocity and effective stress of rock, the clay content and the porosity of the rock are respectively established according to the formation pressure cause types of a loading cause mechanism and an unloading cause mechanism, then a multiparameter formation pressure calculation scheme based on the loading and unloading mechanism is established by utilizing an effective stress principle, and technical support is provided for guaranteeing safe drilling.

The beneficial effects of one of the implementation manners of the above embodiments of the disclosure include at least: acquiring logging data of the mudstone of the abnormal high-pressure interval, and calculating the overlying strata pressure based on the logging data; determining a cause mechanism type, and generating vertical effective stress based on an equation corresponding to the cause mechanism type and the logging data; and calculating the target formation pressure based on the overburden pressure and the vertical effective stress, so that the prediction accuracy of the formation pressure can be greatly improved.

Embodiment III:

with continued reference to fig. 4, a flow 400 of a third embodiment of a formation pressure calculation method according to the present disclosure is shown, which may be performed by the computing device 101 of fig. 1. The formation pressure calculation method comprises the following steps:

step 401, acquiring logging information of a target abnormally high pressure stratum at a target depth in a drilling process.

Step 402, generating an intersection chart with a rock density value as an abscissa and a shale acoustic wave velocity value as an ordinate based on the shale acoustic wave velocity curve and the rock density curve in the logging data.

Step 403, calculating an overburden pressure value based on the sonic velocity value, the rock density value and the mud line threshold in the logging data.

And step 404, judging the causative mechanism of the target abnormal high-pressure stratum based on the slope of the intersection map.

Step 405, if the slope of the intersection is not greater than the preset first threshold, determining that the cause mechanism is a loading mechanism.

Step 406, when the cause mechanism is a loading mechanism, acquiring a rock porosity value, a rock shale content value and a rock longitudinal wave velocity value of the logging data at the target depth, and generating the vertical effective stress by combining a preset loading mechanism equation, wherein the loading mechanism equation is used for representing a functional relation between the rock longitudinal wave velocity and the vertical effective stress, the rock porosity and the rock shale content of the rock.

Step 407, if the slope of the intersection is not less than the preset second threshold, determining that the cause mechanism is an offload mechanism.

In step 408, when the cause mechanism is an unload mechanism, a starting point of the intersection graph corresponding to the target depth is obtained.

And 409, obtaining the maximum sonic wave velocity and the maximum vertical effective stress of the unloading interval rock corresponding to the starting point.

And 410, generating the vertical effective stress by combining a preset unloading mechanism equation based on the rock longitudinal wave velocity value, the rock shale content value and the rock longitudinal wave velocity value at the target depth in the logging data, and the maximum acoustic wave velocity and the maximum vertical effective stress, wherein the unloading mechanism equation is used for representing a functional relation between the rock longitudinal wave velocity and the maximum acoustic wave velocity of the unloading interval rock, the vertical effective stress value of the rock, the maximum vertical effective stress of the unloading interval rock, the rock porosity value and the rock shale content value.

In some alternative implementations, the specific implementation of steps 401 to 410 and the technical effects thereof may refer to steps 201 to 204 in the second embodiment corresponding to fig. 2, which are not described herein.

All the above optional solutions may be combined arbitrarily to form an optional embodiment of the present application, which is not described here in detail.

Embodiment four:

the following are device embodiments of the present disclosure that may be used to perform method embodiments of the present disclosure. For details not disclosed in the embodiments of the apparatus of the present disclosure, please refer to the embodiments of the method of the present disclosure.

With further reference to fig. 5, as an implementation of the methods described above for the various figures, the present disclosure provides an embodiment of a formation pressure calculation device that corresponds to the embodiment described above with respect to fig. 2.

As shown in fig. 5, the formation pressure calculation apparatus 500 of the present embodiment includes:

an acquisition module 501, configured to acquire logging data of a target abnormally high pressure stratum at a target depth in a drilling process;

a discriminating module 502 for discriminating a causative mechanism of a target abnormally high pressure formation based on the logging data, and calculating overburden pressure;

a generating module 503, configured to generate a vertical effective stress based on the cause mechanism and the logging data;

A calculation module 504 is configured to calculate a target formation pressure based on the overburden pressure and the vertical effective stress.

In some embodiments, the loading mechanism equation includes:

In some embodiments, the offload mechanism equation is:

It will be appreciated that the modules described in the apparatus 500 correspond to the various steps in the method described with reference to fig. 2. Thus, the operations, features and resulting benefits described above with respect to the method are equally applicable to the apparatus 500 and the modules contained therein, and are not described in detail herein.

Fifth embodiment:

as shown in fig. 6, the electronic device 600 may include a processing means (e.g., a central processing unit, a graphics processor, etc.) 601, which may perform various appropriate actions and processes according to a program stored in a Read Only Memory (ROM) 602 or a program loaded from a storage means 608 into a Random Access Memory (RAM) 603. In the RAM 603, various programs and data required for the operation of the electronic apparatus 600 are also stored. The processing device 601, the ROM 602, and the RAM 603 are connected to each other through a bus 604. An input/output (I/O) interface 605 is also connected to bus 604.

In general, the following devices may be connected to the I/O interface 605: input devices 606 including, for example, a touch screen, touchpad, keyboard, mouse, camera, microphone, accelerometer, gyroscope, and the like; an output device 607 including, for example, a Liquid Crystal Display (LCD), a speaker, a vibrator, and the like; storage 608 including, for example, magnetic tape, hard disk, etc.; and a communication device 609. The communication means 609 may allow the electronic device 600 to communicate with other devices wirelessly or by wire to exchange data. While fig. 6 shows an electronic device 600 having various means, it is to be understood that not all of the illustrated means are required to be implemented or provided. More or fewer devices may be implemented or provided instead. Each block shown in fig. 6 may represent one device or a plurality of devices as needed.

In particular, according to the present embodiment, the process described above with reference to the flowcharts may be implemented as a computer software program. For example, the present embodiment includes a computer program product comprising a computer program embodied on a computer readable medium, the computer program containing program code for performing the method shown in the flowchart. In the present embodiment, the computer program can be downloaded and installed from a network through the communication means 609, or installed from the storage means 608, or installed from the ROM 602. When the computer program is executed by the processing means 601, the following steps may be performed:

In some embodiments, the loading mechanism equation includes:

wherein V represents the rock longitudinal wave velocity value, sigma _ev Represents the vertical effective stress value of the rock, phi represents the porosity value of the rock, V _sh Representing the value of the shale content, A,B. C, D, E are all constant coefficients.

In some embodiments, the offload mechanism equation is:

wherein V represents the rock longitudinal wave velocity, vm represents the maximum acoustic wave velocity of the unloading interval rock; sigma (sigma) _ev Representing the vertical effective stress value of rock, sigma _m Representing the maximum vertical effective stress of the unloaded interval rock, phi representing the rock porosity value; v (V) _sh The rock mass content values are represented, a ', B', C ', D' being constant coefficients.

It should be noted that, in this embodiment, the computer readable medium may be a computer readable signal medium or a computer readable storage medium, or any combination of the two. The computer readable storage medium can be, for example, but not limited to, an electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or a combination of any of the foregoing. More specific examples of the computer-readable storage medium may include, but are not limited to: an electrical connection having one or more wires, a portable computer diskette, a hard disk, a Random Access Memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disc read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing. In this embodiment, a computer-readable storage medium may be any tangible medium that can contain, or store a program for use by or in connection with an instruction execution system, apparatus, or device. In the present embodiment, however, the computer-readable signal medium may include a data signal propagated in baseband or as part of a carrier wave, with the computer-readable program code embodied therein. Such a propagated data signal may take any of a variety of forms, including, but not limited to, electro-magnetic, optical, or any suitable combination of the foregoing. A computer readable signal medium may also be any computer readable medium that is not a computer readable storage medium and that can communicate, propagate, or transport a program for use by or in connection with an instruction execution system, apparatus, or device. Program code embodied on a computer readable medium may be transmitted using any appropriate medium, including but not limited to: electrical wires, fiber optic cables, RF (radio frequency), and the like, or any suitable combination of the foregoing.

In some implementations, the clients, servers may communicate using any currently known or future developed network protocol, such as HTTP (HyperText Transfer Protocol ), and may be interconnected with any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include a local area network ("LAN"), a wide area network ("WAN"), the internet (e.g., the internet), and peer-to-peer networks (e.g., ad hoc peer-to-peer networks), as well as any currently known or future developed networks.

The computer readable medium may be embodied in the apparatus; or may exist alone without being incorporated into the electronic device. The computer readable medium carries one or more programs which, when executed by the electronic device, cause the electronic device to perform the steps of:

The computer program code for carrying out operations of the present embodiments may be written in one or more programming languages, including an object oriented programming language such as Java, smalltalk, C ++ and conventional procedural programming languages, such as the "C" programming language or similar programming languages. The program code may execute entirely on the user's computer, partly on the user's computer, as a stand-alone software package, partly on the user's computer and partly on a remote computer or entirely on the remote computer or server. In the case of a remote computer, the remote computer may be connected to the user's computer through any kind of network, including a Local Area Network (LAN) or a Wide Area Network (WAN), or may be connected to an external computer (for example, through the Internet using an Internet service provider).

The flowcharts and block diagrams in the figures illustrate the architecture, functionality, and operation of possible implementations of systems, methods and computer program products according to various embodiments of the present disclosure. In this regard, each block in the flowchart or block diagrams may represent a module, segment, or portion of code, which comprises one or more executable instructions for implementing the specified logical function(s). It should also be noted that, in some alternative implementations, the functions noted in the block may occur out of the order noted in the figures. For example, two blocks shown in succession may, in fact, be executed substantially concurrently, or the blocks may sometimes be executed in the reverse order, depending upon the functionality involved. It will also be noted that each block of the block diagrams and/or flowchart illustration, and combinations of blocks in the block diagrams and/or flowchart illustration, can be implemented by special purpose hardware-based systems which perform the specified functions or acts, or combinations of special purpose hardware and computer instructions.

The modules described in the present embodiment may be implemented by software or hardware. The described modules may also be provided in a processor.

The functions described above herein may be performed, at least in part, by one or more hardware logic components. For example, without limitation, exemplary types of hardware logic components that may be used include: a Field Programmable Gate Array (FPGA), an Application Specific Integrated Circuit (ASIC), an Application Specific Standard Product (ASSP), a system on a chip (SOC), a Complex Programmable Logic Device (CPLD), and the like.

The foregoing description is only of the preferred embodiments of the present disclosure and description of the principles of the technology being employed. It will be appreciated by those skilled in the art that the scope of the invention in the embodiments of the present disclosure is not limited to the specific combination of the above technical features, but encompasses other technical features formed by any combination of the above technical features or their equivalents without departing from the spirit of the invention. Such as the above-described features, are mutually substituted with (but not limited to) the features having similar functions disclosed in the embodiments of the present disclosure.

Claims

1. A method of calculating formation pressure, comprising:

2. The method of claim 1, wherein the determining a causative mechanism of a target abnormally high pressure formation based on the log data comprises:

3. The method of claim 2, wherein the generating vertical effective stress based on the causal mechanism and the logging information comprises:

when the causative mechanism is a loading mechanism, acquiring a rock porosity value, a rock shale content value and a rock longitudinal wave velocity value of the logging data at the target depth, and generating the vertical effective stress by combining a preset loading mechanism equation, wherein the loading mechanism equation is used for representing a functional relation between the rock longitudinal wave velocity and the vertical effective stress, the rock porosity and the rock shale content of the rock.

4. A method according to claim 3, wherein the loading mechanism equation comprises:

5. The method of claim 2, wherein the generating vertical effective stress based on the causal mechanism and the logging information comprises:

6. The method of claim 5, wherein the offload mechanism equation is:

7. The method of claim 1, wherein calculating overburden pressure based on the well log data comprises:

8. The method of claim 7, wherein the calculating the overburden pressure value based on the sonic velocity value, the rock density value, and the mud line threshold in the well log data comprises:

9. A formation pressure calculation apparatus, comprising:

10. An electronic device comprising a memory, a processor and a computer program stored in the memory and executable on the processor, characterized in that the processor implements the steps of the method according to any of claims 1 to 8 when the computer program is executed.

11. A computer readable storage medium storing a computer program, characterized in that the computer program when executed by a processor implements the steps of the method according to any one of claims 1 to 8.