CN108733902B

CN108733902B - Method and device for determining permeability of oil reservoir and storage medium

Info

Publication number: CN108733902B
Application number: CN201810414912.1A
Authority: CN
Inventors: 伍晓林; 陈国�; 高淑玲; 刘宏生; 张新亮; 路克微; 魏长清; 马沫然
Original assignee: Petrochina Co Ltd; Daqing Oilfield Co Ltd
Current assignee: Petrochina Co Ltd; Daqing Oilfield Co Ltd
Priority date: 2018-05-03
Filing date: 2018-05-03
Publication date: 2021-11-02
Anticipated expiration: 2038-05-03
Also published as: CN108733902A

Abstract

The invention discloses a method and a device for determining oil reservoir permeability and a storage medium, and belongs to the technical field of oil field development. The method comprises the following steps: the method comprises the steps of obtaining original permeability, original swept reservoir volume, original pore throat ratio and original porosity of a target reservoir, and accumulated produced water volume and suspended matter content in the accumulated produced water at any production moment, determining a first ratio between the throat radius and the original throat radius of the target reservoir at any production moment and a second ratio between the porosity and the original porosity of the target reservoir at any production moment according to obtained parameters, and determining the reservoir permeability of the target reservoir at any production moment according to the first ratio, the second ratio and the original permeability of the target reservoir. The method can determine the permeability of the oil reservoir capable of reflecting the whole oil reservoir by combining dynamic and static production data of the oil reservoir and oil reservoir attributes at different production moments, and improves the accuracy and the calculation efficiency of determining the permeability of the oil reservoir.

Description

Method and device for determining permeability of oil reservoir and storage medium

Technical Field

The invention relates to the technical field of oilfield development, in particular to a method and a device for determining oil reservoir permeability and a storage medium.

Background

The permeability of the oil reservoir refers to the capacity of the whole oil reservoir for allowing fluid to pass under a certain pressure difference, and is an important index for representing the physical properties of the oil reservoir. Along with the continuous development of oil field development, the pore structure in the oil deposit can change, and then leads to the oil deposit permeability to change with time, and the oil deposit permeability is too high, can influence oil field development effect. Therefore, in the actual development process, the oil reservoir permeability at any production moment needs to be determined so as to monitor the change condition of the oil reservoir permeability in real time, find the abnormal change of the oil reservoir permeability in time and make corresponding technical measures, thereby achieving the purpose of oil field oil stabilization and water control.

At present, a core mercury intrusion test is a main means for determining the permeability of an oil reservoir at any production moment. Specifically, the original permeability, the original porosity and the original throat radius of an oil reservoir to be researched can be obtained first, when the oil reservoir permeability of the oil reservoir at the time t needs to be determined, a core section of a certain production well in the oil reservoir at the time t is collected, and a mercury intrusion experiment is performed on the core section by a mercury intrusion instrument in a laboratory, so that the porosity and the throat radius of the core section at the time t are obtained. And then, calculating a first ratio of the porosity of the core section at the time t to the original porosity and a second ratio of the throat radius of the core section at the time t to the original throat radius, determining the permeability of the core section at the time t according to the first ratio, the second ratio and the original permeability, and taking the permeability of the core section at the time t as the reservoir permeability of the reservoir at the time t. The time t can be any production time of the oil reservoir.

In the process of implementing the invention, the inventor finds that at least the following problems exist in the prior art:

the core section is analyzed through a core mercury intrusion experiment, the permeability of the core section is obtained, but the permeability of the core section can only reflect the oil deposit permeability of the corresponding well position of the production well, the oil deposit comprises a plurality of production wells, the oil deposit permeability of the corresponding well position of each production well is different, therefore, the permeability of the core section cannot represent the oil deposit permeability of the whole oil deposit, and the accuracy of the mode of taking the permeability of the core section as the oil deposit permeability of the whole oil deposit is lower. Moreover, the premise of carrying out the core mercury intrusion experiment is to carry out coring operation on the oil reservoir so as to obtain a core section, but the multiple coring operation can increase the investment cost of the oil field and reduce the production efficiency of the oil field.

Disclosure of Invention

In order to solve the problems that the accuracy of determining the permeability of an oil reservoir is low, the investment cost of the oil field can be increased, and the production efficiency of the oil field is reduced in the related technology, the embodiment of the invention provides a method and a device for determining the permeability of the oil reservoir and a storage medium. The technical scheme is as follows:

in a first aspect, a method for determining permeability of a reservoir is provided, the method comprising:

acquiring original permeability, original swept reservoir volume, original pore-throat ratio and original porosity of a target reservoir, and cumulative produced water volume and suspended matter content in the cumulative produced water at a time t, wherein the target reservoir is a reservoir to be researched, and the time t is any production time of the target reservoir;

determining the ratio of the throat radius of the target oil hidden at the time t to the original throat radius according to the original swept reservoir volume, the original pore-throat ratio and the original porosity, and the accumulated produced water volume of the target oil hidden at the time t and the suspended matter content in the accumulated produced water, so as to obtain a first ratio;

determining the porosity of the target oil at the time t according to the original porosity and a preset rule, and determining the ratio of the porosity of the target oil at the time t to the original porosity to obtain a second ratio;

and determining the reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio.

Optionally, the determining, according to the original swept reservoir volume, the original pore-throat ratio, and the original porosity, and the cumulative produced water volume of the target oil reservoir at the time t and the suspended matter content in the cumulative produced water, a ratio between a throat radius of the target oil reservoir at the time t and an original throat radius to obtain a first ratio includes:

and determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore-throat ratio, and determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore-throat ratio as the original swept reservoir volume of the target reservoir.

determining the product of the cumulative produced water volume of the target oil reservoir at the time t and the content of suspended matters in the cumulative produced water, and determining the product of the cumulative produced water volume of the target oil reservoir at the time t and the content of suspended matters in the cumulative produced water as the cumulative produced sediment volume of the target oil reservoir at the time t;

and adding the original swept throat volume and the accumulated silt production volume of the target oil reservoir at the time t to obtain the swept throat volume of the target oil reservoir at the time t.

and determining the arithmetic square root of the ratio between the swept throat volume of the target oil at the time t and the original swept throat volume as the first ratio.

Optionally, the determining, according to the original porosity and by a preset rule, the porosity of the target oil at the time t includes:

and determining the original porosity as the porosity of the target oil hidden at the time t.

determining the swept reservoir volume of the target oil reservoir at the time t;

determining the ratio of the cumulative sediment production volume of the target oil reservoir at the time t to the wave and oil reservoir volume to obtain a third ratio;

and adding the original porosity and the third ratio to obtain the porosity of the target oil reservoir at the time t.

Optionally, the determining the swept reservoir volume of the target oil reservoir at the time t includes:

acquiring the accumulated water passing multiple of the target oil reservoir at the time t;

and determining the ratio of the accumulated water producing volume and the accumulated water passing multiple of the target oil reservoir at the time t as the swept reservoir volume of the target oil reservoir at the time t.

Optionally, the determining the reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio comprises:

determining a product between the original permeability, the first ratio, and an arithmetic square root of the second ratio;

and determining the product of the original permeability, the first ratio and the arithmetic square root of the second ratio as the reservoir permeability of the target oil reservoir at the time t.

In a second aspect, there is provided an apparatus for determining permeability of a reservoir, the apparatus comprising:

the system comprises an acquisition module, a storage module and a control module, wherein the acquisition module is used for acquiring the original permeability, the original swept reservoir volume, the original pore-throat ratio and the original porosity of a target reservoir, and the cumulative produced water volume and the suspended matter content in the cumulative produced water at the moment t, the target reservoir is a reservoir to be researched, and the moment t is any production moment of the target reservoir;

the first determining module is used for determining the ratio of the throat radius of the target oil reservoir at the time t to the original throat radius according to the original swept reservoir volume, the original pore-throat ratio and the original porosity, and the accumulated produced water volume of the target oil reservoir at the time t and the content of suspended matters in the accumulated produced water to obtain a first ratio;

the second determination module is used for determining the porosity of the target oil at the time t according to the original porosity and a preset rule, and determining the ratio of the porosity of the target oil at the time t to the original porosity to obtain a second ratio;

and the third determining module is used for determining the oil reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio.

Optionally, the first determining module includes:

and the first determination unit is used for determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore throat ratio, and determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore throat ratio as the original swept throat volume of the target reservoir.

Optionally, the first determining module includes:

the second determination unit is used for determining the product of the accumulated produced water volume of the target oil reservoir at the time t and the content of suspended matters in the accumulated produced water, and determining the product of the accumulated produced water volume of the target oil reservoir at the time t and the content of suspended matters in the accumulated produced water as the accumulated sediment production volume of the target oil reservoir at the time t;

and the first calculation unit is used for adding the original swept throat volume and the cumulative sediment production volume of the target oil reservoir at the time t to obtain the swept throat volume of the target oil reservoir at the time t.

Optionally, the first determining module includes:

and a third determination unit configured to determine, as the first ratio, an arithmetic square root of a ratio between the swept throat volume at the time t and the original swept throat volume of the target oil reservoir.

Optionally, the second determining module includes:

and the fourth determination unit is used for determining the original porosity as the porosity of the target oil at the time t.

Optionally, the second determining module includes:

a fifth determining unit, configured to determine a swept reservoir volume of the target oil reservoir at the time t;

Optionally, the fifth determining unit includes:

the acquisition subunit is used for acquiring the accumulated water passing multiple of the target oil reservoir at the time t;

and the first determining subunit is used for determining the ratio of the accumulated water production volume and the accumulated water passing multiple of the target oil reservoir at the time t as the swept reservoir volume of the target oil reservoir at the time t.

Optionally, the third determining module is specifically configured to:

In a third aspect, a computer-readable storage medium is provided, in which a computer program is stored, which, when executed by a processor, implements any of the methods provided in the first aspect above.

The technical scheme provided by the embodiment of the invention has the following beneficial effects: in the embodiment of the invention, the original permeability, the original swept reservoir volume, the original pore throat ratio and the original porosity of the target reservoir, and the accumulated water production volume and the accumulated suspended matter content of the target oil at the time t can be obtained, then a first ratio between the throat radius of the target oil at the time t and the original throat radius and a second ratio between the porosity of the target oil at the time t and the original porosity are determined according to the obtained parameters, and the reservoir permeability of the target reservoir at the time t is determined according to the original permeability, the first ratio and the second ratio. The oil reservoir index parameters obtained in the embodiment of the invention are all oil reservoir overall parameters and reflect the average level of the target oil reservoir, so the oil reservoir permeability determined by the oil reservoir overall parameters can reflect the oil reservoir permeability of the whole target oil reservoir, and compared with the prior art, the accuracy of determining the oil reservoir permeability is improved. And the overall parameters of the oil reservoir are the existing data generated by the oil field production and development, and can be directly obtained without coring operation on the oil reservoir, so that the acquisition difficulty of the parameters is reduced, the investment cost of the oil field is reduced, and the production efficiency of the oil field is improved.

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 schematic flow chart of a reservoir permeability determination method provided by an embodiment of the invention;

FIG. 2 is a schematic flow diagram of another method for determining permeability of a reservoir according to an embodiment of the present invention;

FIG. 3 is a schematic diagram of a reservoir permeability determination apparatus according to an embodiment of the present invention;

fig. 4 is a schematic structural diagram of a terminal 400 according to 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.

Before explaining the embodiments of the present invention in detail, terms, application scenarios and system architectures related to the embodiments of the present invention are explained separately.

First, terms related to embodiments of the present invention will be described.

Initial permeability

The original permeability refers to the initial permeability at which the reservoir was not under productive development.

Original sweep volume

The original swept reservoir volume refers to the pore volume swept by formation water when the reservoir is not under productive development.

Original porosity

The original porosity is the ratio of the sum of all pore volumes in the reservoir to the reservoir volume when the reservoir is not under productive development.

Porosity at time t

the porosity at the time t refers to the ratio of the sum of all pore volumes in the oil reservoir to the volume of the oil reservoir from the time t when the oil reservoir is produced.

Original pore-throat ratio

The original pore-throat ratio is the ratio of the pore diameter to the throat diameter in the reservoir when the reservoir is not under production development.

Cumulative water production volume at time t

the cumulative water production volume at the time t refers to the cumulative water production volume from the time of oil reservoir production to the time t.

the content of suspended matters in the accumulated produced water at the moment t

the content of suspended matters in the accumulative produced water at the time t refers to the ratio of the volume of the suspended matters in the accumulative produced water to the volume of the accumulative produced water when the oil reservoir is produced to the time t.

Next, an application scenario related to the embodiment of the present invention is described.

With the continuous development of oil field development, the pore structure in the target oil reservoir changes, and the permeability of the oil reservoir is increased rapidly. Under the condition, the oil reservoir permeability determining method provided by the invention can accurately and rapidly determine the oil reservoir permeability of a target oil reservoir at any production moment, so as to monitor the occurrence of the condition that the injected water suddenly enters along the dominant seepage channel or forms an inefficient or ineffective water injection cycle due to the rise of the permeability in real time, and set corresponding technical measures in time, thereby achieving the purpose of oil and water stabilization of the oil field. In addition, before the tertiary oil recovery measure is carried out on the oil reservoir, the method can also be applied to determine the oil reservoir permeability at the current moment so as to carry out reasonable scheme design and scientific construction operation.

Finally, a system architecture according to an embodiment of the present invention is described.

The method for determining the permeability of the oil reservoir provided by the embodiment of the invention can be applied to a terminal, and the terminal has a data processing function. Specifically, the terminal may be a smart phone, a tablet computer, a notebook computer, a desktop computer, or other terminals capable of data processing.

Fig. 1 is a schematic flow chart of a reservoir permeability determination method according to an embodiment of the present invention. Referring to fig. 1, the method comprises the steps of:

step 101: the method comprises the steps of obtaining the original permeability, the original swept reservoir volume, the original pore-throat ratio and the original porosity of a target reservoir, and the cumulative produced water volume and the suspended matter content in the cumulative produced water at the moment t, wherein the target reservoir is a reservoir to be researched, and the moment t is any production moment of the target reservoir.

Step 102: and determining the ratio of the throat radius of the target oil reservoir at the time t to the original throat radius according to the original swept reservoir volume, the original pore-throat ratio and the original porosity, and the accumulated produced water volume of the target oil reservoir at the time t and the content of suspended matters in the accumulated produced water, so as to obtain a first ratio.

Step 103: and determining the porosity of the target oil at the time t according to the original porosity and a preset rule, and determining the ratio of the porosity of the target oil at the time t to the original porosity to obtain a second ratio.

Step 104: and determining the oil reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio.

In the embodiment of the invention, the original permeability, the original swept reservoir volume, the original pore throat ratio and the original porosity of a target reservoir, and the accumulated produced water volume and the accumulated suspended matter content of target oil at the time t are obtained, then a first ratio between the throat radius of the target oil at the time t and the original throat radius and a second ratio between the porosity of the target oil at the time t and the original porosity are determined according to the obtained parameters, and the reservoir permeability of the target oil at the time t is determined according to the original permeability, the first ratio and the second ratio. The oil reservoir index parameters obtained in the embodiment of the invention are all oil reservoir overall parameters and reflect the average level of the target oil reservoir, so the oil reservoir permeability determined by the oil reservoir overall parameters can reflect the oil reservoir permeability of the whole target oil reservoir, and compared with the prior art, the accuracy of determining the oil reservoir permeability is improved. And the overall parameters of the oil reservoir are the existing data generated by the oil field production and development, and can be directly obtained without coring operation on the oil reservoir, so that the acquisition difficulty of the parameters is reduced, the investment cost of the oil field is reduced, and the production efficiency of the oil field is improved.

Optionally, determining a ratio between the throat radius of the target oil reservoir at the time t and the original throat radius according to the original swept reservoir volume, the original pore throat ratio and the original porosity, and the accumulated produced water volume of the target oil reservoir at the time t and the suspended matter content in the accumulated produced water, and obtaining a first ratio, including:

and determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore-throat ratio, and determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore-throat ratio as the original swept throat volume of the target reservoir.

determining the product of the accumulated produced water volume of the target oil at the time t and the content of suspended matters in the accumulated produced water, and determining the product of the accumulated produced water volume of the target oil at the time t and the content of suspended matters in the accumulated produced water as the volume of accumulated produced sediment of the target oil at the time t;

and adding the original swept throat volume and the accumulated sediment production volume of the target oil at the time t to obtain the swept throat volume of the target oil at the time t.

and determining the arithmetic square root of the ratio between the swept throat volume of the target oil at the time t and the original swept throat volume as a first ratio.

Optionally, determining the porosity of the target oil at the time t according to the original porosity by a preset rule, including:

the original porosity, determined as the porosity of the target oil at time t.

Optionally, the determining the swept reservoir volume of the target oil reservoir at time t includes:

acquiring the accumulated water passing multiple of the target oil at the moment t;

Optionally, determining the reservoir permeability of the target oil reservoir at time t according to the original permeability, the first ratio and the second ratio, including:

All the above optional technical solutions can be combined arbitrarily to form an optional embodiment of the present invention, which is not described in detail herein.

FIG. 2 is a schematic flow chart of another method for determining permeability of a reservoir according to an embodiment of the present invention. Referring to fig. 2, the method comprises the steps of:

step 201: the method comprises the steps of obtaining the original permeability, the original swept reservoir volume, the original pore-throat ratio and the original porosity of a target reservoir, and the cumulative produced water volume and the suspended matter content in the cumulative produced water at the moment t, wherein the target reservoir is a reservoir to be researched, and the moment t is any production moment of the target reservoir.

In the embodiment of the invention, when the oil reservoir permeability of the target oil reservoir at the time t needs to be determined, the original permeability, the original swept volume, the original pore-throat ratio and the original porosity of the oil reservoir, and the 6 parameters of the cumulative produced water volume of the oil reservoir at the time t and the suspended matter content in the cumulative produced water at the time t can be obtained, so that the oil reservoir permeability of the target oil reservoir at the time t can be determined according to the 6 parameters.

The original permeability refers to the reservoir permeability of the target oil reservoir at a corresponding time point when the permeability change starts to be calculated, and the corresponding time point when the permeability change starts to be calculated can be any time point. In practical application, the original permeability can be obtained by user input, can be obtained by sending from other equipment, and can also be obtained by analyzing logging or other experimental data of the target oil reservoir. For example, a plurality of cores of a target reservoir during non-productive development may be collected, experimental analysis may be performed on the plurality of cores in a laboratory to obtain permeabilities of the plurality of cores, and an average value of the permeabilities of the plurality of cores may be determined as an original permeability.

The original swept reservoir volume refers to the pore volume swept by formation water at a time point corresponding to the time point when the target oil reservoir begins to calculate the permeability change, and the time point for starting to calculate the permeability change can be any time point. In practical application, the original swept volume of the oil reservoir can be obtained by user input, can be obtained by sending from other equipment, and can also be obtained by analyzing logging or other experimental data of the target oil reservoir. For example, a plurality of cores of a target reservoir during non-productive development can be collected, experimental analysis is performed on the plurality of cores in a laboratory to obtain water saturations of the plurality of cores, and an original wave and reservoir volume of the cores are determined by using an average value of the water saturations of the plurality of cores, an original porosity of the target reservoir and a reservoir volume of the target reservoir.

The original porosity is the ratio of the sum of all pore volumes of the target oil reservoir at the time point of starting to calculate the permeability change to the reservoir volume, and the time point of starting to calculate the permeability change can be any time point. In practical application, the original porosity can be obtained by user input, can be obtained by sending from other equipment, and can also be obtained by logging or geological analysis of a target oil reservoir. For example, the original porosity of the target reservoir may be determined using a pore-permeability relationship chart or formula derived from a well log interpretation curve.

Wherein, the original pore-throat ratio refers to the ratio of the pore diameter of the target oil reservoir at the time point of starting to calculate the permeability change to the throat diameter, and the time point of starting to calculate the permeability change can be any time point. In practical application, the original pore-throat ratio can be obtained by user input, can be obtained by sending from other equipment, and can also be obtained by logging of a target oil reservoir or analysis of core data. For example, the original pore throat ratio is determined using core mercury intrusion experimental parameters.

The cumulative water production volume at the time t refers to the cumulative water production volume when the target oil reservoir is produced to a certain time. In practical application, the cumulative water production volume at the time t can be obtained by user input, can be sent by other equipment, and can also be obtained by analyzing the production data of the target oil reservoir. For example, the cumulative water production volume at time t is obtained by counting the cumulative water production volume until time t of the target reservoir production.

And the content of the suspended matters in the accumulative produced water at the moment t is the ratio of the volume of the suspended matters contained in the accumulative produced water to the volume of the accumulative produced water when the target oil reservoir is produced to the moment t. In practical application, the content of suspended matters in the accumulated produced water at the time t can be obtained by user input, can be sent by other equipment, and can also be obtained by analyzing the production data of the oil reservoir. For example, the suspended matter content in the accumulated produced water until t moment of target oil reservoir production is counted, the ratio of the volume of suspended matter contained in the accumulated produced water to the volume of the accumulated produced water is calculated, and the suspended matter content in the accumulated produced water at t moment is determined.

For convenience of illustration, the original permeability can be expressed as K in the examples of the present invention₀Representation, original sweep and reservoir volume V_r0Expression, original pore-throat ratio by gamma, original porosity by

V for cumulative water production volume at time t_wThe suspended matter content in the cumulative produced water at time t is represented by α.

Taking a certain block of the target oil reservoir A as an example, the method provided by the invention can be applied to determine the oil reservoir permeability of the block. Assuming that the block was put into operation starting in 1965 and the permeability of the reservoir of the block at the end of the years of different production was determined from 1965, the original porosity, original swept reservoir volume, original pore-throat ratio and original permeability of the block could be obtained prior to putting into operation. E.g. obtained

28.5% of V_r0Is 1.95X 10⁶m³Gamma is 35, K₀Is 1145 mD.

In addition, after the block is put into production, the accumulated produced water volume and the suspended matter content in the accumulated produced water of the block at any production moment can be obtained. For example, table 1 shows the cumulative produced water volume and the suspended matter content in the cumulative produced water at the end of the 6 years 1988-2015 of the block, wherein the first column is the year corresponding to the acquired reservoir index parameter, the second column is the cumulative produced water volume, and the third column is the suspended matter content in the cumulative produced water.

TABLE 1

It should be noted that, in the embodiment of the present invention, only the original reservoir index parameter assumed above and the reservoir index parameter of each year in table 1 are described, but the above assumption and table 1 do not limit the reservoir index parameters.

Step 202: and determining the ratio of the throat radius of the target oil reservoir at the time t to the original throat radius according to the original swept reservoir volume, the original pore-throat ratio and the original porosity, and the accumulated produced water volume of the target oil reservoir at the time t and the content of suspended matters in the accumulated produced water, so as to obtain a first ratio.

Specifically, step 202 can be implemented by steps 2021-2024 as follows:

step 2021:and determining the ratio of the product of the original swept reservoir volume and the original porosity to the original pore-throat ratio to obtain the original swept throat volume of the target reservoir.

Specifically, the original swept throat volume of the target reservoir can be obtained by using the following formula (1) according to the original swept reservoir volume, the product of the original porosity and the original pore throat ratio:

wherein, V₀Is originally swept of the throat volume, V_r0In order to have the original sweep over the reservoir volume,

γ is the original pore throat ratio for the original porosity.

For example, when the target reservoir is produced by the end of 1988, and V_r0Is 1.95X 10⁶m³，

28.5%, and gamma 35,

step 2022:and determining the product of the accumulated produced water volume of the target oil at the time t and the content of suspended matters in the accumulated produced water to obtain the accumulated produced sediment volume of the target oil at the time t.

Specifically, the cumulative sediment production volume at the t moment of the target oil reservoir can be obtained by adopting the following formula (2) according to the cumulative water production volume at the t moment and the suspended matter content in the cumulative produced water at the t moment:

V_s＝V_wα (2)

wherein, V_sFor cumulative silt production at time tProduct of qi and blood_wIs the cumulative water production volume at the time t, and alpha is the content of suspended matters in the cumulative water production at the time t.

For example, when the target reservoir is produced by the end of 1988, and V_wIs 4155553.9m³Alpha is 120X 10^-6When, V_s＝V_wα＝4155553.9×120×10^-6＝498.7(m³)。

Step 2023:and adding the original swept throat volume and the accumulated sediment production volume of the target oil at the time t to obtain the swept throat volume of the target oil at the time t.

Specifically, the swept throat volume at the t moment of the target oil reservoir can be obtained by adopting the following formula (3) according to the original swept throat volume and the cumulative silt production volume at the t moment:

V_t＝V₀+V_s (3)

wherein, V_tSwept throat volume at time t, V₀Is originally swept of the throat volume, V_sThe cumulative sediment production volume at time t.

For example, when the target reservoir is produced by the end of 1988, and V₀＝15878m³、V_s＝498.7m³When, V_t＝V₀+V_s＝15878+498.7＝16376.7(m³)。

Step 2024:and determining the arithmetic square root of the ratio between the swept throat volume of the target oil at the time t and the original swept throat volume as a first ratio.

Specifically, the first ratio of the target reservoir at the time t can be obtained by adopting the following formula (4) according to the swept throat volume and the original swept throat volume at the time t:

r_t/r₀＝(V_t/V₀)^1/2 (4)

wherein r is_tRadius of throat at time t, r₀Is the original throat radius, V_tSwept throat volume at time t, V₀The original swept throat volume.

Wherein r in the above formula (4)_t/r₀Namely the first ratio.

For example, when the target reservoir is produced by the end of 1988, and V_tIs 16376.7m³、V₀＝15878m³When r is_t/r₀＝(V_t/V₀)^1/2＝(16376.7÷15878)^1/2＝1.016。

Step 203: and determining the porosity of the target oil at the t moment according to the original porosity and a preset rule.

The porosity at the time t refers to the porosity of the target oil reservoir from the time t when the target oil reservoir is produced, and the swept reservoir volume at the time t refers to the pore volume swept by the formation water from the time t when the target oil reservoir is produced. For convenience of illustration, the embodiment of the present invention may use the porosity at time t

Representing and using the swept reservoir volume at time t as V_rtAnd (4) showing.

Specifically, the preset rule in step 203 is implemented by the following two ways:

the first implementation mode comprises the following steps:determining the original porosity as the porosity of the target oil at the time t;

specifically, in the first implementation, the porosity at time t can be determined using the following equation (5):

wherein the content of the first and second substances,

is the porosity at the time t,

is the original porosity.

That is, the embodiment of the invention can determine the original porosity as the porosity of the target reservoir at any moment as the porosity of the target reservoir is unchanged, and the implementation mode simplifies the calculation process of the porosity at the moment t, saves the time for obtaining the second ratio, and is suitable for a scene of quickly calculating the permeability of the target reservoir at the moment t.

The second implementation mode comprises the following steps:determining the swept reservoir volume of the target oil reservoir at the time t; determining the ratio of the cumulative sediment production volume of the target oil reservoir at the time t to the swept reservoir volume to obtain a third ratio; and adding the original porosity and the third ratio to obtain the porosity of the target oil at the t moment.

Specifically, the operation of determining the swept reservoir volume of the target oil reservoir at time t may include: acquiring the accumulated water passing multiple of the target oil at the moment t; and determining the ratio of the accumulated water producing volume and the accumulated water passing multiple of the target oil reservoir at the time t as the swept reservoir volume of the target oil reservoir at the time t.

For example, the swept reservoir volume at time t may be determined using equation (6) below:

V_rt＝V_w/β (6)

wherein, V_rtSwept reservoir volume at time t, V_wThe cumulative water production volume at the time t, and beta is the cumulative water passing multiple at the time t.

The cumulative water passing multiple is the ratio of the cumulative volume of injected water passing through the target oil deposit between the injection well and the production well to the swept pore volume. In practical application, the accumulated water passing multiple can be obtained by user input, can be obtained by sending from other equipment, and can also be obtained by calculating the production data of the oil reservoir. For example, the cumulative volume of water injected through and the swept pore volume between an injection well and a production well in the target reservoir may be obtained, and the cumulative water cut factor may be determined by calculating the ratio of the cumulative volume of water injected through to the swept pore volume.

The accumulated sediment production volume of the target oil at the time t can be obtained by multiplying the accumulated sediment production volume of the target oil at the time t by the content of suspended matters in the accumulated sediment production water.

For example, after determining the swept reservoir volume at time t of the target reservoir, the porosity of the target oil reservoir at time t can be determined using equation (7) below:

wherein the content of the first and second substances,

is the porosity at the time t,

to original porosity, V_sThe cumulative sediment volume, V, of time t_rtThe swept reservoir volume at time t.

The implementation mode considers that the porosity in the target oil reservoir changes along with the change of time, the influence of the porosity change on the determined permeability is considered, the actual production condition of the target oil reservoir is better fitted, the permeability of the target oil reservoir at the time t determined by the implementation mode is more comprehensive than the permeability of the target oil reservoir at the time t, and the calculation precision is higher.

Specifically, according to the original porosity, the porosity of the target oil reservoir at the time t is determined through a preset rule, and two implementation modes of the preset rule can be selected by a technician according to the data preparation condition of the oil reservoir.

Step 204: and determining the ratio between the porosity of the target oil at the t moment and the original porosity as a second ratio.

That is, the ratio between the porosity at the target oil reservoir at time t and the original porosity may be calculated, and the ratio between the porosity at the target oil reservoir at time t and the original porosity may be taken as the second ratio. E.g. computing

And

the ratio therebetween is

And will be

As a second ratio.

Step 205: and determining the oil reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio.

Specifically, the operation of determining the reservoir permeability of the target oil reservoir at time t according to the original permeability, the first ratio and the second ratio may include: determining a product between the original permeability, the first ratio, and the arithmetic square root of the second ratio; and determining the product of the original permeability, the first ratio and the arithmetic square root of the second ratio as the reservoir permeability of the target oil reservoir at the time t.

For example, the reservoir permeability of the target oil reservoir at time t may be determined from the original permeability, the first ratio and the second ratio using the following equation (8):

wherein, K_tPermeability of the reservoir at time t, K₀In order to obtain the original permeability of the water,

in order to be the original porosity level,

porosity at time t, r_tRadius of throat at time t, r₀Is the original throat radius.

Wherein r is_t/r₀It is shown that the first ratio is,

a second ratio is indicated.

For example, taking a certain block of the target reservoir a in the above step 101 as an example, assuming that the porosity of the block at the end of 1988 is determined by the first implementation manner in the above step 203, the reservoir permeability of the block at the end of 1988 can be calculated according to the above formula (8) as:

further, still taking a certain block of the target reservoir a in the above step 101 as an example, assuming that the porosity of the block in the generation process is determined by the first implementation in the above step 203, the obtained reservoir permeability of the block at the end of 1996, 2003, 2008, 2013 and 2015 years can be shown in the following table 2, respectively. The first column in table 2 is a year corresponding to the acquired oil reservoir index parameter, the second column is an accumulated silt production volume Vs at the bottom of the corresponding year, the third column is a swept throat volume Vt at the bottom of the corresponding year, the fourth column is a ratio of a throat radius at the bottom of the corresponding year to an original throat radius, the fifth column is a permeability change rate at the bottom of the corresponding year, the sixth column is a calculated oil reservoir permeability at the bottom of the corresponding year, the seventh column is a measured oil reservoir permeability at the bottom of the corresponding year, and the eighth column is a relative error between a measured value and a calculated value at the bottom of the corresponding year.

The permeability change rate refers to a ratio of a difference value between the oil reservoir permeability and the original oil reservoir permeability of the block calculated at the end of each year to the original oil reservoir permeability, the calculated oil reservoir permeability refers to the oil reservoir permeability of the block at the end of the corresponding year calculated by the method provided by the embodiment of the invention, the measured oil reservoir permeability refers to a plurality of cores of a target oil reservoir obtained by the block at the end of the corresponding year, the cores are analyzed in a laboratory to obtain the permeability of the cores, the average value of the permeability of the cores is used for determining the oil reservoir permeability of the block in the whole reaction oil reservoir at the end of the corresponding year, and the relative error between the measured value and the calculated value refers to a ratio of the difference value between the measured oil reservoir permeability and the calculated oil reservoir permeability to the measured oil reservoir permeability.

TABLE 2

Table 2 shows the law of increasing reservoir permeability with increasing development time of the reservoir. Moreover, the relative error between the oil reservoir permeability value obtained by calculation through the first preset rule and the measured permeability value is close to 10% at most, and the oil reservoir permeability calculated by the method is high in accuracy.

For example, assuming that the porosity of the block in the end of 1988 is determined by the second implementation manner in step 203, the porosity of the block in the end of 1988 can be calculated according to the above equations (6) and (7), and the reservoir permeability of the block in the end of 1988 can be calculated according to the above equation (8) as follows:

calculating the swept reservoir volume of the block from production to the end of 1988 according to the formula (6):

V_rt＝V_w/β＝4155553.9÷6.9＝602254.2(m³)；

the porosity of the block produced by the end of 1988 was calculated according to equation (7):

calculating according to the formula (8) to obtain the oil reservoir permeability of the block from the production to the end of 1988 as follows:

still taking a certain block of the target reservoir a in the above step 101 as an example, assuming that the porosity of the block in the generation process is determined by the second implementation manner in the above step 203, the obtained reservoir permeability of the block at the end of 1996, 2003, 2008, 2013 and 2015 years can be respectively shown in the following table 3. The first column is a year corresponding to the acquired oil reservoir index parameter, the second column is a cumulative sediment volume Vs at the bottom of the corresponding year, the third column is a swept throat volume Vt at the bottom of the corresponding year, the fourth column is a first ratio at the bottom of the corresponding year, the fifth column is an accumulated water discharge multiple at the bottom of the corresponding year, the sixth column is a swept oil reservoir volume at the bottom of the corresponding year, the seventh column is a porosity at the time t of the bottom of the corresponding year, the eighth column is a calculated permeability change rate at the bottom of the corresponding year, the ninth column is a calculated oil reservoir permeability value at the bottom of the corresponding year, the tenth column is a measured oil reservoir permeability value at the bottom of the corresponding year measured by using the prior art, and the eleventh column is a relative error between the measured value and the calculated value at the bottom of the corresponding year.

The permeability change rate refers to a ratio of a difference value between the calculated oil reservoir permeability and the original oil reservoir permeability of the block at the end of each year to the original oil reservoir permeability, the calculated oil reservoir permeability refers to the oil reservoir permeability of the block at the end of the corresponding year calculated by the method provided by the embodiment of the invention, the measured oil reservoir permeability refers to a plurality of cores of a target oil reservoir obtained by the block at the end of the corresponding year, the cores are analyzed in a laboratory to obtain the permeability of the cores, the integral oil reservoir permeability of the reaction oil reservoir of the block at the end of the corresponding year is determined by using an average value of the permeability of the cores, and the relative error between the measured value and the calculated value refers to a ratio of the difference value between the calculated oil reservoir permeability to the measured oil reservoir permeability.

TABLE 3

Table 3 shows the law of increasing reservoir permeability as the development time of the reservoir increases. Moreover, the relative error between the reservoir permeability value obtained by calculation through the second implementation mode of the preset rule and the measured permeability value is maximally lower than 10%, and the relative error between the reservoir permeability value obtained by calculation before polymer flooding and the measured permeability value is lower than 5%, which indicates that the accuracy of the reservoir permeability obtained by calculation through the method is very high.

The reservoir index parameters in tables 2 and 3 are only used in the examples of the present invention, but tables 2 and 3 do not limit the reservoir index parameters.

Furthermore, according to the method provided by the embodiment of the invention, the oil reservoir permeability of the target oil reservoir at a plurality of different moments is determined, the change rule of the target oil reservoir permeability along with time is researched according to the oil reservoir permeability at the plurality of different moments, the abnormal change of the oil reservoir permeability is timely found, and corresponding technical measures are made, so that the purposes of oil field oil stabilization and water control are achieved. Or, the method provided by the embodiment of the invention can be used for determining the oil reservoir permeability of the target oil reservoir in real time, so as to achieve the purpose of monitoring the oil reservoir permeability of the target oil reservoir in real time.

In the embodiment of the invention, the original permeability, the original swept reservoir volume, the original pore throat ratio and the original porosity of a target reservoir, and the accumulated produced water volume and the accumulated suspended matter content of target oil at the time t are obtained, then a first ratio between the throat radius of the target oil at the time t and the original throat radius and a second ratio between the porosity of the target oil at the time t and the original porosity are determined according to the obtained parameters, and the reservoir permeability of the target oil at the time t is determined according to the original permeability, the first ratio and the second ratio. The obtained oil reservoir index parameters at different production moments are all oil reservoir overall parameters and reflect the average level of the target oil reservoir, so that the oil reservoir permeability determined by the oil reservoir overall parameters can reflect the oil reservoir permeability of the whole target oil reservoir, and the accuracy of determining the oil reservoir permeability is improved compared with the prior art. And the overall parameters of the oil reservoir are the existing data generated by the oil field production and development, and can be directly obtained without coring operation on the oil reservoir, so that the acquisition difficulty of the parameters is reduced, the investment cost of the oil field is reduced, and the production efficiency of the oil field is improved.

Fig. 3 is a schematic structural diagram of a reservoir permeability determination apparatus according to an embodiment of the present invention. Referring to fig. 3, the apparatus may include:

an obtaining module 301, configured to obtain an original permeability, an original swept reservoir volume, an original pore-throat ratio, an original porosity of a target reservoir, and an accumulated produced water volume and an accumulated suspended matter content in produced water at time t, where the target reservoir is a reservoir to be researched and time t is any production time of the target reservoir;

the first determining module 302 is configured to determine a ratio between a throat radius at the time t and an original throat radius of the target oil according to the original swept reservoir volume, the original pore-throat ratio, the original porosity, an accumulated produced water volume at the time t of the target oil reservoir, and a content of suspended matters in the accumulated produced water, and obtain a first ratio;

the second determining module 303 is configured to determine, according to the original porosity and according to a preset rule, the porosity of the target oil at the time t, and determine a ratio between the porosity of the target oil at the time t and the original porosity to obtain a second ratio;

and a third determination module 304, configured to determine the reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio.

Optionally, the first determining module includes:

the first determining unit is used for determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore throat ratio, and determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore throat ratio as the original swept throat volume of the target reservoir.

Optionally, the first determining module includes:

the second determination unit is used for determining the product of the accumulated produced water volume of the target oil at the moment t and the content of suspended matters in the accumulated produced water, and determining the product of the accumulated produced water volume of the target oil at the moment t and the content of suspended matters in the accumulated produced water as the accumulated sediment production volume of the target oil at the moment t;

and the first calculation unit is used for adding the volume of the original swept throat and the cumulative sediment production volume of the target oil at the time t to obtain the volume of the swept throat of the target oil at the time t.

Optionally, the first determining module includes:

and the third determining unit is used for determining the arithmetic square root of the ratio between the swept throat volume of the target oil at the time t and the original swept throat volume as the first ratio.

Optionally, the second determining module includes:

and a fourth determination unit for determining the original porosity as the porosity of the target oil at the time t.

Optionally, the second determining module includes:

the fifth determining unit is used for determining the swept reservoir volume of the target oil reservoir at the time t;

determining the ratio of the cumulative sediment production volume of the target oil reservoir at the time t to the swept reservoir volume to obtain a third ratio;

and adding the original porosity and the third ratio to obtain the porosity of the target oil at the t moment.

Optionally, the fifth determining unit includes:

the acquisition subunit is used for acquiring the accumulated water passing multiple of the target oil at the moment t;

Optionally, the third determining module is specifically configured to:

determining a product between the original permeability, the first ratio, and the arithmetic square root of the second ratio;

In the embodiment of the invention, the oil reservoir permeability of the target oil reservoir at any production moment is determined by acquiring the original permeability, the original swept volume, the original pore throat ratio and the original porosity of the target oil reservoir at any production moment, the accumulated produced water volume and the suspended matter content in the accumulated produced water at any production moment and the porosity of the target oil reservoir at any production moment obtained through a preset rule, the ratio between the throat radius and the original throat radius of the target oil reservoir at any production moment and the ratio between the porosity and the original porosity are determined, and the oil reservoir permeability of the target oil reservoir at any production moment is determined according to the ratio between the throat radius and the original throat radius, the ratio between the porosity and the original permeability. That is, the dynamic and static production data of the target oil reservoir and the target oil reservoir attributes at different production moments, which are obtained in the embodiment of the present invention, are the overall parameters of the oil reservoir, which reflect the average level of the target oil reservoir, and the oil reservoir permeability of the target oil reservoir at any production moment, which is determined by the overall parameters of the oil reservoir, is the average oil reservoir permeability of the oil reservoir, which improves the accuracy of determining the oil reservoir permeability compared with the prior art. Moreover, the overall oil reservoir parameters are the existing data generated by the production and development of the oil field, so that the acquisition difficulty of the overall oil reservoir parameters is reduced, the calculation efficiency is improved, the oil reservoir coring times are reduced, and the production efficiency of the oil field is improved.

It should be noted that: the oil reservoir permeability determining device provided in the above embodiment is only illustrated by the division of the above functional modules when determining the oil reservoir permeability, and in practical application, the function distribution may be completed by different functional modules according to needs, that is, the internal structure of the device is divided into different functional modules to complete all or part of the functions described above. In addition, the oil reservoir permeability determining device provided by the above embodiment and the method embodiment for determining the oil reservoir permeability belong to the same concept, and the specific implementation process is described in the method embodiment, and is not described herein again.

Fig. 4 is a schematic structural diagram of a terminal 400 according to an embodiment of the present invention. The terminal 400 may be: a smart phone, a tablet computer, an MP3 player (Moving Picture Experts Group Audio Layer III, motion video Experts compression standard Audio Layer 3), an MP4 player (Moving Picture Experts Group Audio Layer IV, motion video Experts compression standard Audio Layer 4), a notebook computer, or a desktop computer. The terminal 400 may also be referred to by other names such as user equipment, portable terminal, laptop terminal, desktop terminal, etc.

Generally, the terminal 400 includes: a processor 401 and a memory 402.

Processor 401 may include one or more processing cores, such as a 4-core processor, an 8-core processor, or the like. The processor 401 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 401 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 401 may be integrated with a GPU (Graphics Processing Unit), which is responsible for rendering and drawing the content required to be displayed by the display screen. In some embodiments, the processor 401 may further include an AI (Artificial Intelligence) processor for processing computing operations related to machine learning.

Memory 402 may include one or more computer-readable storage media, which may be non-transitory. Memory 402 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 402 is used to store at least one instruction for execution by processor 401 to implement the reservoir permeability determination methods provided by the method embodiments herein.

In some embodiments, the terminal 400 may further optionally include: a peripheral interface 403 and at least one peripheral. The processor 401, memory 402 and peripheral interface 403 may be connected by bus or signal lines. Each peripheral may be connected to the peripheral interface 403 via a bus, signal line, or circuit board. Specifically, the peripheral device includes: at least one of a radio frequency circuit 404, a touch screen display 404, a camera 406, an audio circuit 407, a positioning component 408, and a power supply 409.

The peripheral interface 403 may be used to connect at least one peripheral related to I/O (Input/Output) to the processor 401 and the memory 402. In some embodiments, processor 401, memory 402, and peripheral interface 403 are integrated on the same chip or circuit board; in some other embodiments, any one or two of the processor 401, the memory 402 and the peripheral interface 403 may be implemented on a separate chip or circuit board, which is not limited by this embodiment.

The Radio Frequency circuit 404 is used for receiving and transmitting RF (Radio Frequency) signals, also called electromagnetic signals. The radio frequency circuitry 404 communicates with communication networks and other communication devices via electromagnetic signals. The rf circuit 404 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 404 includes: 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 404 may communicate with other terminals via at least one wireless communication protocol. The wireless communication protocols include, but are not limited to: metropolitan area networks, various generation mobile communication networks (2G, 3G, 4G, and 4G), Wireless local area networks, and/or WiFi (Wireless Fidelity) networks. In some embodiments, the rf circuit 404 may further include NFC (Near Field Communication) related circuits, which are not limited in this application.

The display screen 404 is used to display a UI (User Interface). The UI may include graphics, text, icons, video, and any combination thereof. When the display screen 405 is a touch display screen, the display screen 405 also has the ability to capture touch signals on or over the surface of the display screen 405. The touch signal may be input to the processor 401 as a control signal for processing. At this point, the display screen 405 may also be 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 display screen 405 may be one, providing the front panel of the terminal 400; in other embodiments, the display screen 405 may be at least two, respectively disposed on different surfaces of the terminal 400 or in a folded design; in still other embodiments, the display 405 may be a flexible display disposed on a curved surface or a folded surface of the terminal 400. Even further, the display screen 405 may be arranged in a non-rectangular irregular pattern, i.e. a shaped screen. The Display screen 405 may be made of LCD (Liquid Crystal Display), OLED (Organic Light-Emitting Diode), and other materials.

The camera assembly 406 is used to capture images or video. Optionally, camera assembly 406 includes a front camera and a rear camera. Generally, a front camera is disposed at a front panel of the terminal, and a rear camera is disposed at a rear surface of the terminal. In some embodiments, the number of the rear cameras is at least two, and each rear camera is any one of a main camera, a depth-of-field camera, a wide-angle camera and a telephoto 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 panoramic shooting and VR (Virtual Reality) shooting functions or other fusion shooting functions. In some embodiments, camera assembly 406 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.

The audio circuit 407 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 401 for processing, or inputting the electric signals to the radio frequency circuit 404 for realizing voice communication. For the purpose of stereo sound collection or noise reduction, a plurality of microphones may be provided at different portions of the terminal 400. 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 401 or the radio frequency circuit 404 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 407 may also include a headphone jack.

The positioning component 408 is used to locate the current geographic position of the terminal 400 for navigation or LBS (Location Based Service). The Positioning component 408 may be a Positioning component based on the GPS (Global Positioning System) of the united states, the beidou System of china, the graves System of russia, or the galileo System of the european union.

The power supply 409 is used to supply power to the various components in the terminal 400. The power source 409 may be alternating current, direct current, disposable or rechargeable. When power source 409 comprises a rechargeable battery, the rechargeable battery may support wired or wireless charging. The rechargeable battery may also be used to support fast charge technology.

In some embodiments, the terminal 400 also includes one or more sensors 410. The one or more sensors 410 include, but are not limited to: acceleration sensor 411, gyro sensor 412, pressure sensor 413, fingerprint sensor 414, optical sensor 415, and proximity sensor 416.

The acceleration sensor 411 may detect the magnitude of acceleration in three coordinate axes of the coordinate system established with the terminal 400. For example, the acceleration sensor 411 may be used to detect components of the gravitational acceleration in three coordinate axes. The processor 401 may control the touch display screen 405 to display the user interface in a landscape view or a portrait view according to the gravitational acceleration signal collected by the acceleration sensor 411. The acceleration sensor 411 may also be used for acquisition of motion data of a game or a user.

The gyro sensor 412 may detect a body direction and a rotation angle of the terminal 400, and the gyro sensor 412 may cooperate with the acceleration sensor 411 to acquire a 3D motion of the terminal 400 by the user. From the data collected by the gyro sensor 412, the processor 401 may implement the following functions: 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 413 may be disposed on a side bezel of the terminal 400 and/or a lower layer of the touch display screen 405. When the pressure sensor 413 is disposed on the side frame of the terminal 400, a user's holding signal to the terminal 400 can be detected, and the processor 401 performs left-right hand recognition or shortcut operation according to the holding signal collected by the pressure sensor 413. When the pressure sensor 413 is disposed at the lower layer of the touch display screen 405, the processor 401 controls the operability control on the UI interface according to the pressure operation of the user on the touch display screen 405. 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 414 is used for collecting a fingerprint of the user, and the processor 401 identifies the identity of the user according to the fingerprint collected by the fingerprint sensor 414, or the fingerprint sensor 414 identifies the identity of the user according to the collected fingerprint. Upon recognizing that the user's identity is a trusted identity, processor 401 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 414 may be disposed on the front, back, or side of the terminal 400. When a physical key or vendor Logo is provided on the terminal 400, the fingerprint sensor 414 may be integrated with the physical key or vendor Logo.

The optical sensor 415 is used to collect the ambient light intensity. In one embodiment, the processor 401 may control the display brightness of the touch display screen 405 based on the ambient light intensity collected by the optical sensor 415. Specifically, when the ambient light intensity is high, the display brightness of the touch display screen 405 is increased; when the ambient light intensity is low, the display brightness of the touch display screen 405 is turned down. In another embodiment, the processor 401 may also dynamically adjust the shooting parameters of the camera assembly 406 according to the ambient light intensity collected by the optical sensor 415.

A proximity sensor 416, also known as a distance sensor, is typically disposed on the front panel of the terminal 400. The proximity sensor 416 is used to collect the distance between the user and the front surface of the terminal 400. In one embodiment, when the proximity sensor 416 detects that the distance between the user and the front surface of the terminal 400 gradually decreases, the processor 401 controls the touch display screen 405 to switch from the bright screen state to the dark screen state; when the proximity sensor 416 detects that the distance between the user and the front surface of the terminal 400 gradually becomes larger, the processor 401 controls the touch display screen 405 to switch from the breath screen state to the bright screen state.

That is, not only is an embodiment of the present invention provide a terminal including a processor and a memory for storing processor-executable instructions, where the processor is configured to execute the method in the embodiment shown in fig. 1 or fig. 2, but also an embodiment of the present invention provides a computer-readable storage medium, in which a computer program is stored, and the computer program, when executed by the processor, can implement the reservoir permeability determination method in the embodiment shown in fig. 1 or fig. 2.

Those skilled in the art will appreciate that the configuration shown in fig. 4 is not intended to be limiting of terminal 400 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.

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 for determining permeability of a reservoir, the method comprising:

determining the reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio;

determining the ratio of the throat radius of the target oil reservoir at the time t to the original throat radius according to the original swept reservoir volume, the original pore-throat ratio and the original porosity, and the accumulated produced water volume of the target oil reservoir at the time t and the suspended matter content in the accumulated produced water, and obtaining a first ratio, wherein the first ratio comprises:

determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore-throat ratio, and determining the ratio between the product of the original swept reservoir volume and the original porosity and the original pore-throat ratio as the original swept throat volume of the target reservoir;

adding the original swept throat volume and the accumulated silt production volume of the target oil reservoir at the time t to obtain the swept throat volume of the target oil reservoir at the time t;

determining the arithmetic square root of the ratio between the swept throat volume of the target oil at the time t and the original swept throat volume as the first ratio;

wherein the determining the porosity of the target oil at the time t according to the original porosity by a preset rule comprises:

determining the original porosity as the porosity of the target oil at the time t;

or determining the swept reservoir volume of the target reservoir at the time t;

adding the original porosity and the third ratio to obtain the porosity of the target oil reservoir at the time t;

wherein the determining the reservoir permeability of the target oil reservoir at the time t according to the original permeability, the first ratio and the second ratio comprises:

determining a product between the original permeability, a square of the first ratio, and the second ratio;

and determining the product of the original permeability, the square of the first ratio and the second ratio as the reservoir permeability of the target oil reservoir at the time t.

2. The method of claim 1, wherein the determining the swept reservoir volume of the target oil reservoir at the time t comprises:

3. The method of claim 1, wherein the raw permeability is obtained by:

collecting a plurality of rock cores of the target oil reservoir which are not subjected to production development;

carrying out experimental analysis on the plurality of rock cores to obtain the permeability of the plurality of rock cores;

determining an average value of the permeabilities of the plurality of cores as the original permeability.

4. The method of claim 1, wherein the original porosity is determined from a pore-permeability plot obtained using a well log interpretation curve.

5. The method of claim 1, wherein the raw swept reservoir volume is obtained by:

collecting a plurality of rock cores of the target oil reservoir when production development is not carried out;

carrying out experimental analysis on the plurality of rock cores to obtain the water saturation of the plurality of rock cores;

and determining the original wave and reservoir volume according to the average value of the water saturation of the cores, the original porosity of the target reservoir and the reservoir volume of the target reservoir.

6. The method of claim 1, wherein the raw pore throat ratio is determined using core mercury intrusion experimental parameters.

7. An apparatus for determining permeability of a reservoir, the apparatus comprising:

a third determining module, configured to determine, according to the original permeability, the first ratio, and the second ratio, a reservoir permeability of the target oil reservoir at the time t;

8. The apparatus of claim 7, wherein the second determining module is further to: acquiring the accumulated water passing multiple of the target oil reservoir at the time t;

9. A computer-readable storage medium, in which a computer program is stored which, when being executed by a processor, carries out the method of any one of claims 1 to 6.