CN114925547A

CN114925547A - Method and device for determining dosage of water shutoff agent, electronic equipment and storage medium

Info

Publication number: CN114925547A
Application number: CN202210706858.4A
Authority: CN
Inventors: 冯青; 曾鸣; 李胜胜; 李啸南; 黄子俊; 孙艳妮
Original assignee: China Oilfield Services Ltd
Current assignee: China Oilfield Services Ltd
Priority date: 2022-06-21
Filing date: 2022-06-21
Publication date: 2022-08-19

Abstract

The invention relates to a method and a device for determining the dosage of a water shutoff agent, wherein the method is used for predetermining a multilayer oil reservoir model of an agent region to be injected, and comprises the following steps: determining the flow rate of a first small layer after injection of the agent according to the multilayer oil reservoir model, wherein the first small layer is the small layer with the highest permeability; determining the expected effect coefficient of the water shutoff agent in the area to be injected with the agent according to the flow splitting rate of the first small layer after injection of the agent and the flow splitting rate of the ith small layer after injection of the agent; determining the permeability of the first small layer after injection according to the flow split rate of the first small layer after injection; determining the acting radius of the water shutoff agent in the area to be injected according to the expected effect coefficient of the water shutoff agent and the permeability of the first small layer after injection; and calculating a model and the acting radius of the water shutoff agent according to the preset amount of the water shutoff agent, and determining the amount of the water shutoff agent in the area to be injected. By the method, the oil deposit pollution caused by excessive injection due to inaccurate dosage of the water shutoff agent is avoided, or the sand consolidation and water shutoff effects cannot be realized due to too small dosage of the water shutoff agent.

Description

Method and device for determining dosage of water shutoff agent, electronic equipment and storage medium

Technical Field

The invention belongs to the field of oilfield development, and particularly relates to a method and a device for determining the using amount of a water shutoff agent, electronic equipment and a storage medium.

Background

High water content and sand production are two main problems which restrict high and stable yield of most offshore oil fields, and in the existing lots of low-efficiency low-yield shut-in wells, the wells which are shut-in directly due to sand control failure occupy a very high proportion. And at present, most of the water content of a part of offshore oil fields is about 90 percent, and the offshore oil fields enter a high water content development stage. The offshore loose sandstone reservoir stratum has strong heterogeneity, and injected water is easy to rush along a high permeability layer.

The inventor of the application finds out in research that how to solve the problems of high water content and sand production of the oil field so as to ensure high and stable yield of the oil well, and is a difficult problem to be solved urgently in the industry.

Disclosure of Invention

In order to solve the technical problems, the invention aims to provide a method and a device for determining the dosage of a water shutoff agent, electronic equipment and a storage medium, so that the dosage of the sand control water shutoff agent is determined, the water content of an oil well is reduced, the oil content of an extracting solution is increased, the sand control water shutoff effect is enhanced, and the oil field recovery ratio is improved.

According to one aspect of the application, a method for determining the usage amount of a water shutoff agent is provided, a multilayer reservoir model of an agent region to be injected is predetermined, the multilayer reservoir model comprises n small layers with different permeabilities, and the method comprises the following steps:

determining the flow rate a of a first small layer after injection of the agent according to the multilayer oil reservoir model, wherein the first small layer is the small layer with the highest permeability;

according to the flow splitting rate a after the first small layer of injected agent and the flow splitting rate f 'after the ith small layer of injected agent' _i Determining the expected effect coefficient M of the water shutoff agent in the area to be injected,

wherein i is more than or equal to 2 and less than or equal to n;

determining the permeability K 'of the first small layer injected with the agent according to the flow dividing rate a of the first small layer injected with the agent' ₁ ；

According to the expected effect coefficient M of the water shutoff agent and the permeability K 'of the first small layer after agent injection' ₁ Determining the action radius r of the water shutoff agent in the area to be injected by a Darcy radial flow equation _p ；

Calculating a model according to the preset dosage of the water shutoff agent and the action radius r of the water shutoff agent _p And determining the dosage V of the water shutoff agent in the area to be injected.

In an alternative form, the after-injection flow split ratio f 'of the ith small layer' _i Determined by the steps of:

obtaining the permeability K before the injection of the ith small layer in the multilayer oil reservoir model _i And the effective thickness h of the ith small layer _i For determining the flow rate Q before injection of the ith sub-layer _i ；

According to the flow rate Q before the injection of the ith small layer _i And the total flow rate Q of the area to be injected determines the flow splitting rate f before injecting the agent in the ith small layer _i ；

According to the split flow rate f of the ith small layer before injection _i Determining the flow division rate f 'after the injection of the ith small layer' _i 。

In an optional mode, after the agent injection region is injected with the water shutoff agent, the first small layer comprises a water shutoff region and an outer region; the determination of the permeability K 'of the first small layer after injection' ₁ The method comprises the following steps:

obtaining the permeability K of the water plugging area _1g And permeability K of said outer zone ₁ ；

Obtaining the oil well borehole radius r of the multilayer oil reservoir model _w Oil well supply radius r _e Pressure difference Deltap between well bottom and stratum, and viscosity mu of stratum water _w And the skin factor S of the reservoir;

according to the permeability K of the water plugging area _1g And permeability K of said outer zone ₁ The radius r of the oil well borehole _w The oil well supply radius r _e Pressure difference Δ p between the well bottom and the formation, viscosity μ of the formation water _w And determining the skin coefficient S of the reservoir, and determining the permeability K 'of the first small layer after injection' ₁ 。

In an optional mode, a model and the action radius r of the water shutoff agent are calculated according to the preset dosage of the water shutoff agent _p Determining the dosage V of the water shutoff agent in the area to be injected with the agent, comprising the following steps:

according to the permeability K of the water plugging area _1g And permeability K of said outer zone ₁ Determining the residual resistivity F of the water shutoff agent _r ；

Obtaining the effective thickness H of the region to be injected with the agent and the porosity of the region to be injected with the agent

According to the residual resistivity F of the water plugging agent _r The effective thickness H of the region to be injected with the agent and the porosity of the region to be injected with the agent

The water shutoff agent has an action radius r _p And determining the dosage V of the water shutoff agent.

In an optional manner, after determining the usage amount V of the water shutoff agent, the method further includes:

after the dosage V of the water shutoff agent in the area to be injected is determined, the method further comprises the following steps:

obtaining the performance evaluation result of the water shutoff agent;

acquiring an additional multiple F according to the performance evaluation result of the water shutoff agent;

and correcting the dosage V of the water shutoff agent through the dosage calculation model of the water shutoff agent according to the additional multiple F.

In an alternative mode, the evaluation result of the performance of the water shutoff agent includes a sand production rate and a core damage rate, and the obtaining of the additional multiple F includes:

acquiring the actual permeability of the region to be injected with the agent after injection;

and obtaining the additional multiple F according to the sand production rate, the core damage rate and the actual permeability of the area to be injected with the agent after injection.

According to another aspect of the present application, there is provided a water shutoff agent usage amount determination device, the device including: the model building module is used for determining an agent injection area according to the logging data and building a multilayer oil reservoir model; the after-injection split-flow rate determining module is used for determining the split-flow rate a of a first small layer after injection of the agent according to the multilayer oil reservoir model, wherein the first small layer is the small layer with the highest permeability; an expected effect coefficient determining module for determining the flow splitting rate a ' of the first small layer injected with the water shutoff agent and the flow splitting rate f ' of the ith small layer injected with the agent according to the flow splitting rate a of the first small layer injected with the water shutoff agent and the flow splitting rate f ' _i Determining the expected effect coefficient M of the water shutoff agent in the area to be injected; a post-injection permeability determining module for determining the permeability K 'of the first small layer after injection according to the flow rate a of the first small layer after injection' ₁ (ii) a The water shutoff agent action radius determining module is used for determining the permeability K 'of the first small layer injected agent according to the expected effect coefficient M of the water shutoff agent' ₁ Determining the action radius r of the water shutoff agent in the area to be injected by the Darcy radial flow equation _p (ii) a A water shutoff agent dosage determination module used for calculating a model according to the preset water shutoff agent dosage and the water shutoff agent action radius r _p And determining the dosage V of the water shutoff agent in the area to be injected.

In an optional manner, the apparatus further comprises: the evaluation result acquisition module is used for acquiring the performance evaluation result of the water shutoff agent after determining the dosage V of the water shutoff agent; the additional multiple acquisition module is used for acquiring an additional multiple F according to the performance evaluation result of the water shutoff agent; and the correction module is used for correcting the dosage V of the water shutoff agent through the dosage calculation model of the water shutoff agent according to the additional multiple F.

According to another aspect of the present application, there is provided an electronic device comprising at least one processor; and a memory and a communication component communicatively coupled to the at least one processor; the memory stores instructions executable by the at least one processor, and the instructions, when executed by the at least one processor, establish a data channel through the communication component, so that the at least one processor can execute any one of the foregoing methods for determining an amount of the water shutoff agent.

According to another aspect of the present application, there is provided a non-transitory computer-readable storage medium storing computer-executable instructions for causing a computer to execute any one of the above methods for determining an amount of a water shutoff agent.

According to the embodiment of the application, a multilayer reservoir model is established for the actual environmental conditions of an oil well and a stratum, the heterogeneity factors such as the expected effect of the water shutoff agent are considered, the water shutoff effect of the water shutoff agent in the area to be injected can be accurately determined by calculating the action radius of the water shutoff agent, the using amount of the water shutoff agent is accurately determined, the calculation of the using amount of the water shutoff agent is greatly optimized, the method is accurate, simple and feasible, the overhigh cost caused by the fact that a large amount of the water shutoff agent is injected is avoided, effective sand control of the water shutoff agent on the stratum can be guaranteed, the oil yield of the oil well is improved, the area injected with the water shutoff agent has high sand control strength and low stratum damage rate, and meanwhile, the plugging area has good oil-water selective plugging capacity.

The foregoing description is only an overview of the technical solutions of the present application, and the present application can be implemented according to the content of the description in order to make the technical means of the present application more clearly understood, and the following detailed description of the present application is given in order to make the above and other objects, features, and advantages of the present application more clearly understandable.

Drawings

Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the application. Also, like reference numerals are used to refer to like parts throughout the drawings. In the drawings:

fig. 1 is an application scenario diagram of a water shutoff agent in an embodiment of the present application;

FIG. 2 is a schematic diagram of a multi-layer reservoir model according to an embodiment of the present application;

fig. 3 is a flowchart of a method for determining the amount of a water shutoff agent in an embodiment of the present application;

fig. 4 is a schematic view illustrating an effect of the water shutoff agent in an embodiment of the present application;

FIG. 5 is a schematic view of the structure of the water shut-off region and the outer region in an embodiment of the present application;

fig. 6 is another flowchart of a method for determining an amount of a water shutoff agent in an embodiment of the present application;

fig. 7 is another flowchart of a method for determining an amount of a water shutoff agent in an embodiment of the application;

fig. 8 is another flowchart of a method for determining an amount of a water shutoff agent in an embodiment of the present application;

FIG. 9 is a schematic structural view of a water shut-off region and an outer region according to an embodiment of the present application;

FIG. 10 is a schematic diagram illustrating the plugging rate of the FSG sand-controlling plugging agent on a water layer and an oil layer at different temperatures in an embodiment of the present application;

FIG. 11 is a graph of E10 well production in one embodiment of the present application;

fig. 12 is a schematic structural diagram of a device for determining an amount of a water shutoff agent in an embodiment of the present application;

fig. 13 is a schematic structural diagram of an electronic device according to an embodiment of the present application.

Detailed Description

Embodiments of the present invention will be described in detail below with reference to the accompanying drawings. The following examples are only used to illustrate the technical solutions of the present application more clearly, and therefore are only used as examples, and the protection scope of the present application is not limited thereby.

Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs; the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the application; the terms "including" and "having," and any variations thereof in the description and claims of this application and the description of the figures above, are intended to cover non-exclusive inclusions.

In the description of the embodiments of the present application, the technical terms "first", "second", and the like are used only for distinguishing different objects, and are not to be construed as indicating or implying relative importance or implicitly indicating the number, specific order, or primary-secondary relationship of the technical features indicated.

Reference herein to "an embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment can be included in at least one embodiment of the application. The appearances of the phrase in various places in the specification are not necessarily all referring to the same embodiment, nor are separate or alternative embodiments mutually exclusive of other embodiments. It is explicitly and implicitly understood by one skilled in the art that the embodiments described herein can be combined with other embodiments.

In the description of the embodiments of the present application, the term "and/or" is only one kind of association relationship describing an associated object, and means that three relationships may exist, for example, a and/or B, and may mean: a exists alone, A and B exist simultaneously, and B exists alone. In addition, the character "/" herein generally indicates that the former and latter related objects are in an "or" relationship.

In the description of the embodiments of the present application, the term "plurality" refers to two or more (including two), and similarly, "plural sets" refers to two or more (including two), and "plural pieces" refers to two or more (including two).

In the description of the embodiments of the present application, the terms "center", "longitudinal", "lateral", "length", "width", "thickness", "up", "down", "front", "back", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", "clockwise", "counterclockwise", "axial", "radial", "circumferential", and the like, indicate the directions or positional relationships indicated in the drawings, and are only for convenience of description of the embodiments of the present application and for simplicity of description, but do not indicate or imply that the referred device or element must have a specific direction, be constructed and operated in a specific direction, and thus, should not be construed as limiting the embodiments of the present application.

In the description of the embodiments of the present application, unless otherwise explicitly specified or limited, the terms "mounted," "connected," "fixed," and the like are to be construed broadly, e.g., as meaning fixedly connected, detachably connected, or integrated; mechanical connection or electrical connection is also possible; either directly or indirectly through an external agent, either internally or in any combination thereof. Specific meanings of the above terms in the embodiments of the present application can be understood by those of ordinary skill in the art according to specific situations.

At present, most of oil reservoirs at the initial stage of offshore oil field exploitation can drive crude oil and natural gas to be sprayed to the ground through an oil well pipe column by means of the original stratum pressure of an oil layer, however, along with continuous spraying of oil gas, the pressure inside the stratum is gradually reduced, when the residual pressure of the oil layer is lower than the back pressure caused by the liquid pressure in the oil well pipe column, the oil well stops oil injection, and secondary exploitation is needed at the moment. The 'oil reservoir water injection' is a main means of secondary oil recovery, and is characterized in that water injection wells are drilled at alternate positions of an oil well, and residual crude oil in a stratum is pushed to the bottom of the oil well from the deep part of the stratum through a high-pressure water injection pump and is sprayed to the ground.

However, the pore structure of the rock core of the stratum can be changed and the permeability can be increased due to the long-term water injection development, and rock fragments can be flushed into the oil well barrel under the condition that stratum rocks are flushed by a large amount of water, namely 'sand production'. Sand production can result in increased water content and decreased oil production from the well. Meanwhile, due to the reasons of loose reservoir cementation, high crude oil viscosity, strong sand carrying capacity of fluid and the like, a high-permeability layer is flushed out of a large pore passage in the long-term water injection development process, a large amount of injected water enters along the large pore passage suddenly, the water content of an oil well rises rapidly, ineffective circulation of water injection is caused, the water drive efficiency is greatly reduced, and the pressure of platform water treatment is increased more and more.

The inventor of the application finds that sand consolidation and water plugging can be performed on a stratum which is easy to produce sand by injecting the water plugging agent into an oil well, but the determination of the using amount of the water plugging agent is a difficult point existing at present. The excessive water shutoff agent can cause economic loss, and the water shutoff agent can enter the stratum which does not need sand consolidation and water shutoff to cause damage to the stratum and oil reservoir pollution; the requirement of sand consolidation and water plugging can not be met when the using amount of the water plugging agent is too small, so that a method capable of accurately determining the using amount of the water plugging agent is needed, the water plugging agent has a high sand consolidation and water plugging effect after being injected, meanwhile, overlarge damage to a stratum can be avoided, and the problems of easy sand production and high water content existing in the current offshore oil field are solved.

In view of this, an embodiment of the present application provides a method for determining a usage amount of a water shutoff agent, which includes creating a multi-layer reservoir model in consideration of multi-layer and heterogeneity effects of an oil well in advance, and determining a splitting rate f 'of a first small layer with a highest permeability according to the created multi-layer reservoir model' ₁ Determining the expected effect coefficient M of the water shutoff agent of the area to be injected with the agent and the permeability K 'of the first small layer after injection of the agent' ₁ Then according to the expected effect coefficient M of the water shutoff agent and the permeability K 'after the injection of the first small layer' ₁ Determining the action radius r of the water shutoff agent in the area to be injected with the agent _p Determining the action radius r of the water shutoff agent _p Then, calculating a model and the action radius r of the water shutoff agent according to the preset amount of the water shutoff agent _p And determining the dosage V of the water plugging agent required by the area to be injected. The method for determining the dosage of the water shutoff agent considers the expected effect M of the water shutoff agent, the multilayer structure and the heterogeneity of the stratum and the action radius r of the water shutoff agent _p The calculation can be carried out, the water plugging effect of the water plugging agent in the area to be plugged can be accurately determined, the using amount of the water plugging agent is accurately determined, the calculation of the using amount of the water plugging agent is greatly optimized, the method is accurate, simple and easy to implement, the overhigh cost caused by the injection of a large amount of the water plugging agent is avoided, the effective plugging and sand control of the water plugging agent on the stratum can be ensured, the oil production of an oil well is improved, the area after the injection of the water plugging agent has high sand prevention strength and low stratum damage rate, and meanwhile, the plugging area has good oil-water selective plugging capability.

Referring to fig. 1, fig. 1 shows an application scenario of the water shutoff agent, where X is a water injection well, and is used to inject water into an oil layer in a formation B through the water injection well X after being pressurized by a high-pressure water injection pump, so as to supplement the pressure of the oil layer, and to extract oil in the formation B to a bottom surface through an oil extraction well Y. Because the oil layer is cemented and loosened, the structure of the oil layer is changed in the long-term water injection and scouring process of the water injection well X, so that the water content of the oil well rises rapidly, the sand of the oil well is produced, and the water plugging and sand control of the oil layer are needed. The specific measures are that a position needing water shutoff, such as an agent to be injected area A, is found through stratum parameters, and then a certain amount of water shutoff agent is injected into the agent to be injected area A, so that sand control and water shutoff are carried out on an oil well, and the oil exploitation is facilitated.

Aiming at the phenomena of high water content and serious sand production of the oil well, the embodiment of the application adopts a water and sand blocking measure that a precise dosage of FSG (free-standing Gel, vast free Gel) sand control water blocking agent is injected into the area A to be injected. Because the FSG sand-controlling water shutoff agent is a semi-solid colloid, namely non-Newtonian fluid, which is in a net structure formed by mutually connecting colloidal particles, macromolecules or surfactant molecules, after entering a hypertonic layer of an agent region to be injected, the FSG sand-controlling water shutoff agent can absorb water to expand to block pores in a stratum, and the integration of chemical sand prevention and water shutoff of an oil well is realized. The method for determining the dosage of the water shutoff agent is provided for the FSG sand control water shutoff agent, so that the sand control water shutoff effect of an oil reservoir after the FSG sand control water shutoff agent is used by an oil well can be improved, and the oil field recovery ratio is improved.

According to an aspect of an embodiment of the present application, with continuing reference to fig. 1 and further referring to fig. 2, a method for determining a multilayer reservoir model of an agent injection region is provided, wherein the multilayer reservoir model comprises n small layers with different permeabilities, as shown in fig. 2.

When a multi-layer reservoir model is established, the actual structure of the region to be injected needs to be considered. As shown in fig. 1, a in fig. 1 is an area to be injected, and it can be seen in fig. 1 that the stratum of the area to be injected is multi-layered and non-homogeneous, the distribution structure of the stratum is discrete, and as the amount of water injected into the oil reservoir increases, the injection profile of the area to be injected a is very non-uniform, some small layers have higher water content, and some small layers have lower water content, so in the multi-layered reservoir model shown in fig. 2, n small layers with different permeabilities are pre-established to simulate the flow state of fluid in the stratum before and after injection under the real conditions of the oil well to be injected.

Multilayer oilThe reservoir model is established according to the oil well parameters of the area to be injected in the logging data and the formation parameters under the oil well. As shown in FIG. 2, well parameters include well feed radius r _e And the well bore radius r _w The stratum parameters comprise stratum distribution form, stratum type, stratum layer number n, stratum effective thickness H and stratum porosity

And the like. Wherein the effective thickness H of the region to be injected is the effective thickness H of each small layer _i Average effective thickness of sum, porosity of region to be impregnated

Average porosity which is the sum of the porosities of each sublayer.

Carrying out indoor simulation test according to the established multilayer oil reservoir model to obtain a test result, and analyzing the test result so as to obtain stratum change parameters of an oil well to be injected before and after water plugging operation, wherein the stratum change parameters specifically comprise: permeability K before injection of i-th small layer _i Permeability K 'after injection of the ith sub-layer' _i The flow rate of the oil well is measured by the following steps of (1) total formation flow rate Q, flow rate Qi before injection of an ith small layer, flow rate Q' i after injection of the ith small layer, original formation pressure, bottom hole flowing pressure, pressure difference delta p between the bottom hole and the formation, skin coefficient S, production data before and after water plugging operation of the oil well and the like.

According to the method and the device, the multilayer oil reservoir model is established by simulating the to-be-injected agent region of the heterogeneous oil reservoir, so that an indoor simulation test is closer to a real condition, a better fitting effect is achieved, the accuracy of an indoor simulation test result is improved, and the accuracy of the determination of the water shutoff agent consumption is improved. As shown in fig. 3, the method for determining the usage amount of the water shutoff agent includes:

s100, determining the flow rate a of a first small layer after injection of the agent according to the multilayer oil reservoir model, wherein the first small layer is the small layer with the highest permeability.

FIG. 4 is a schematic diagram illustrating the effect of the water shutoff agent according to an embodiment of the present application, and as shown in FIG. 4, the water shutoff agent is superior during the water shutoff operation of the oil wellThe plugging agent acts on the small layer with the highest permeability, and then enters a low-permeability stratum, so that the area to be injected is effectively plugged, and the crude oil recovery rate of water injection development is improved. As shown in FIG. 4, K ₃ The minor layer closest to the water, which has the highest permeability, is identified as the first minor layer in the examples of this application; in sequence K ₂ A second sublayer having a permeability less than the first sublayer; k ₁ Is the third sublayer, the permeability of which is less than that of the second sublayer, and so on. In FIG. 4, the permeability of the plurality of small layers is K ₃ ＞K ₂ ＞K ₁ Therefore, the water shutoff agent will act on the small layer K with the highest permeability first ₃ Then to other small layers K ₂ And K ₁ And (6) plugging.

In the embodiment of the application, the first small layer is set to be completely blocked after the water plugging agent is injected, the flow rate of the first small layer after the agent is injected is set as a, the first small layer is completely blocked after the water plugging agent is injected, the average permeability of the first small layer is reduced, and the permeability of other small layers is kept unchanged.

The numerical simulation method is used for setting the flow splitting rate after the small layer with the highest permeability is injected into the area to be injected with the water shutoff agent, and compared with the problems that the prediction is difficult, the calculated amount is large and the considered data is incomplete in other methods for determining the using amount of the water shutoff agent such as a profile control radius method or a fuzzy mathematical method, the dynamic data before and after the formation injection of the area to be injected with the water shutoff agent is simulated through the numerical simulation method and the establishment of a multi-layer oil reservoir model, more comprehensive formation data are considered, and the accurate using amount of the water shutoff agent required by an oil well is predicted more quickly and accurately.

S200, according to the flow splitting ratio a after the first small layer is injected with the agent and the flow splitting f 'after the ith small layer is injected with the agent' _i Determining the expected effect coefficient of the water shutoff agent in the area to be injected with the agent

Wherein i is more than or equal to 2 and less than or equal to n.

In an indoor test, the expected effect coefficient of the water shutoff agent is set to be M,

wherein i is a sublayer number, and f 'since the flow dividing rate after the injection of the first sublayer is determined to be a in step S100' ₁ A, therefore, the flow split f 'after injection of the ith small layer' _i Excluding the first small layer, 2 ≦ i ≦ n, the expected effectiveness factor M may be converted to:

and establishing a water plugging agent dosage calculation model according to the multilayer oil reservoir model, and determining an expected effect coefficient M of the water plugging agent in the water plugging agent dosage calculation model so as to ensure that the water plugging agent dosage V calculated according to the water plugging agent dosage calculation model can enable the area to be injected to achieve the required sand-fixing water plugging effect.

S300, determining the permeability K 'of the first small layer after injection of the agent according to the flow dividing rate a of the first small layer after injection of the water shutoff agent' ₁

Since the stratum is a porous structure, the flow of water after the injection of the water shutoff agent into the first small layer can cause the change of the pore structure and the seepage rate (permeability and flow velocity) of the first small layer, and the flow splitting rate f 'after the injection of the agent into the first small layer is determined' ₁ After a, it is also necessary to determine the post-injection permeability K 'of the first small layer' ₁ 。

S400, according to the expected effect coefficient M of the water shutoff agent and the permeability K 'of the first small layer after injection' ₁ Determining the action radius r of the water shutoff agent in the area to be injected by the Darcy radial flow equation _p 。

The Darcy radial flow equation is also called Darcy's law and is used for describing the rule of the linear relation between the seepage velocity of water in saturated soil and hydraulic gradient, also called linear seepage law, and specifically describes that the seepage flow of water passing through a porous medium in unit time is inversely proportional to the length of a seepage path and is used for expressing that the seepage rule of underground water in rock pores follows the Darcy law.

Combining a multilayer reservoir model with an expected effect coefficient M and the permeability K 'after the first small layer injection' ₁ Determining the action radius r of the water shutoff agent according to the radial flow equation of Darcy _p 。

The water shutoff agent acts on the oil well supply radius r after being injected into the area to be injected with the agent _e And the well bore radius r _w Thus requiring a given well feed radius r _e Radius r of oil well bore _w Thereby determining the action radius r of the water shutoff agent _p As shown in fig. 5.

Oil well supply radius r _e The distance from the edge of the area of the stratum where the crude oil flows into the oil well to the center of the oil well; radius r of oil well borehole _w I.e., the radius of the well, can be determined by the caliper or the size of the drilling tool while drilling.

Through presetting the expected effect coefficient M and the permeability K 'after injection of the first small layer' ₁ Determining the action radius r of the water shutoff agent _p Determining the action radius r of the water shutoff agent by using a calculation model of the water shutoff agent dosage _p The method is more effective and rapid, the calculated amount is smaller, and the operation is stable; and comprehensively considers a plurality of parameters such as stratum parameters, oil well parameters and the like to ensure the determined acting radius r of the water shutoff agent _p More accurate, thereby the water shutoff agent dosage V of confirming is more reliable, is changeed and reaches the demand to oil well water shutoff, and then improves the oil production of oil well.

S500, calculating a model according to the preset dosage of the water shutoff agent and the action radius r of the water shutoff agent _p And determining the dosage V of the water shutoff agent in the area to be injected.

The action radius r of the water shutoff agent determined in the step S400 _p Combining the effective thickness H of the region to be injected and the porosity of the region to be injected obtained from the logging data

And obtaining the Pore Volume (PV) of the stratum, and further determining the dosage V of the water shutoff agent.

According to the method for determining the dosage of the water shutoff agent, stratum parameters of a region to be injected with the agent are combined with a model for calculating the dosage of the water shutoff agent through a numerical method, the expected effect M of the water shutoff agent and the heterogeneity factor of the stratum are considered, and the radius r of the action on the water shutoff agent is determined _p Perform calculation to obtainThe method has the advantages that the water plugging effect of the water plugging agent in the area to be plugged is determined, so that the using amount V of the water plugging agent is accurately determined, the calculation of the using amount V of the water plugging agent is greatly optimized, the method is accurate, simple and feasible, the overhigh cost caused by the injection of a large amount of the water plugging agent is avoided, the effective plugging and sand control of the water plugging agent on the stratum can be ensured, the oil production of an oil well is improved, the area after the injection of the water plugging agent has high sand prevention strength and low stratum damage rate, and meanwhile, the plugging area has good oil-water selective plugging capability.

In order to realize more accurate determined dosage of the water shutoff agent and match with the actual water shutoff situation required by the oil well to be injected with the agent, the embodiment of the application is further provided, as shown in fig. 6, the flow split rate f 'after the i-th small layer of the agent is injected' _i Is determined by the following steps:

s210, obtaining the permeability K before injection of the ith small layer in the multilayer oil reservoir model _i And the effective thickness h of the ith small layer _i For determining the flow rate Q before injection of the ith sub-layer _i 。

Flow rate Q before injection of ith small layer _i Permeability K before injection of ith small layer _i And the effective thickness h of the ith small layer _i The influence is that according to the radial flow equation of Darcy, the flow velocity before injection of the ith small layer is expressed by the following formula:

the total flow rate of the area to be injected with the agent is the sum of the flow rates of the n small layers before injection with the agent and is expressed as follows:

s220, according to the flow rate Q before injection of the ith small layer _i And the total flow rate Q of the area to be injected determines the flow dividing rate f before the injection of the ith small layer _i 。

According to the formula (1) and the formula (2), determining the split flow rate f of the ith small layer before injection _i In the formula (3), f _i The split flow rate and K before injection of the agent into the ith small layer _i Permeability, h, before injection of the i-th sub-layer _i Is the effective thickness of the ith small layer, i is the number of the small layer, wherein i is more than or equal to 2 and less than or equal to n.

S230, according to the flow dividing rate f before the injection of the ith small layer _i Determining the flow division rate f 'after the injection of the ith small layer' _i 。

K 'in the formula' ₁ Is the permeability of the first small layer after injection, unit mD, millidarcy; h is ₁ The effective thickness of the first small layer is m, wherein the effective thickness of each small layer is not influenced by the water plugging agent before and after injection.

After the determined flow rate a of the first small layer injected with the agent in the step S100, the permeability K 'of the first small layer injected with the agent is' ₁ And a first effective sublayer thickness h ₁ Substituting the formula (4) to obtain the flow rate f 'after the injection of the ith small layer' _i After the flow dividing rate a of the first small layer after injection of the agent is determined, the expected effect coefficient M of the water shutoff agent in the area to be injected can be obtained:

wherein i is more than or equal to 2 and less than or equal to n.

Further, in some embodiments, the permeability K 'of the first sublayer is determined for greater accuracy' ₁ Referring to fig. 5, after the water shutoff agent is injected into the agent-to-be-injected region, the first small layer includes a water shutoff region and an outer region; in the figure, the water plugging area 1 is the radius r of the oil well borehole after the water plugging agent is injected _w And well supply radius r _e The permeability of the area is changed along with the injection of the water plugging agent; in fig. 5 the outer zone comprises a middle zone 2 and an oil drainage gallery zone 3, being the well bore radius r _w And well supply radius r _e The area between the two areas is constant in permeability after the water plugging agent is injected. Thus, as shown in FIG. 7, the first small layer post injection permeability K 'was determined' ₁ The method specifically comprises the following steps:

s310, obtaining the permeability K of the water plugging area _1g And permeability K of said outer zone ₁ 。

Assuming that the water shutoff agent flows in the first small layer according to the Darcy radial law, according to the Darcy radial flow equation, the flow speed of the first small layer after injection is as follows:

in the formula, K _1g The permeability of the water plugging area after injection of the agent is expressed in mD;

K ₁ permeability after injection of the agent into the outer region, in mD;

r _w radius of the well bore, unit m;

r _p the radius of action of the water plugging agent is m;

r _e supplying the radius for the well, in m;

delta p is the pressure difference between the bottom of the well and the stratum, and the unit is Mpa;

μ _w formation water viscosity in mPa · s, mPa · s;

s is the epidermis coefficient;

equation (5) is converted as follows:

due to the permeability K 'of the first small layer after injection' ₁ Permeability K including water shut-off zone _1g And permeability K of the outer zone ₁ And the permeability K of the outer zone is also known ₁ Is not affected by the injection of the water plugging agent, so the permeability K of the outer area ₁ The constant permeability is the same as the permeability before the first small layer is injected, so equation (5) can be converted to equation (6).

S320, obtaining the oil well borehole radius r of the multilayer oil reservoir model _w Oil well supply radius r _e Pressure difference Deltap between well bottom and stratum, and viscosity of stratum water mu _w And the skin factor S of the reservoir.

When crude oil flows into an oil well, certain stratum flowing pressure is needed, and after the water shutoff agent is injected, at least one part of small layers with higher water content in the stratum can be completely or partially plugged under the action of the water shutoff agent, so that the flow speed is changed, and therefore, the stratum pressure can also be changed along with the change of the flow speed. The pressure difference delta p between the bottom of the well and the stratum is the change value of the original stratum pressure and the stratum flowing pressure, and can be obtained according to pressure dynamic data acquired by measuring devices such as a pressure sensor during well logging.

The water in the formation is in long-term contact with the rock and formation reservoir, and the formation water viscosity mu is therefore _w Changes occur, the stratum mineralization (salt concentration) of different oil reservoirs is different, the viscosity of stratum water is also different, and the viscosity mu of the stratum water of an oil well can be obtained according to the mineral content of the stratum water in indoor tests according to the influence of temperature and pressure _w 。

The skin coefficient S is also known as the bottom hole drag coefficient and is a comprehensive coefficient used to represent the extent of zone contamination and damage. Because the oil well can pollute the stratum in the drilling or exploitation operation, the permeability of the near-well stratum changes, so that additional resistance is generated, and the pressure recovery explanation obtained by performing indoor simulation test on a multilayer oil reservoir model is obtained by combining the completion mode of the oil well to be injected with the agent.

S330, according to the permeability K of the water plugging area _1g And permeability K of said outer zone ₁ The radius r of the oil well borehole _w The well supply radius r _e The pressure difference Deltap between the well bottom and the stratum and the viscosity mu of the stratum water _w Determining the permeability K 'of the first small layer after injection' ₁ 。

Obtaining the formula (7) from the formula (5) and the formula (6), and obtaining the permeability K 'after the first small layer is injected with the agent' ₁ 。

Further, in some embodiments of the present application, the permeability K 'after the first small layer injection is determined' ₁ Afterwards, the expected effect coefficient M of the water shutoff agent and the permeability K 'of the first small layer after injection can be obtained' ₁ Determining the action radius r of the water shutoff agent in the area to be injected by a Darcy radial flow equation _p . The embodiment of the application also provides the following embodiment mode, which realizes the action radius r of the water shutoff agent in the area to be injected with the agent _p The determination specifically comprises the following steps:

flow split ratio f 'after determination of ith sublayer shot' _i Then, according to the set expected effect coefficient

The flow division ratio f 'of the ith small layer after injection of the agent' _i Substituting the flow rate a after the agent is injected into the first small layer into an expected effect coefficient M to obtain the following formula:

according to the permeability K 'of the first small layer after injection' ₁ Determining the action radius r of the water shutoff agent by combining the expected effect coefficient M _p . Substituting equation (7) into equation (8) yields:

the action radius r of the water plugging agent can be obtained _p And the determination process is quick and accurate.

In some embodiments of the present application, as shown in fig. 8, the radius r of action of the water shutoff agent is determined _p Then, a model and the action radius r of the water shutoff agent can be calculated according to the preset dosage of the water shutoff agent _p Determining the multi-layer reservoir modelThe dosage V of the water plugging agent specifically comprises the following steps:

s510, according to the permeability K of the water plugging area _1g And said outer region K ₁ Determining the residual resistivity F of the water shutoff agent by the ratio of the permeability _r 。

Because the mineral contents of the stratum water are different and the stratum water has different conductivities, after the water plugging agent is used for water plugging operation in the stratum, the mineralization degree and the resistivity of the water can be changed, the water plugging area of the first small layer is completely plugged to form an insulating plugging area, and the permeability K of the water plugging area is compared _1g And permeability K of the outer zone ₁ Obtaining the residual resistivity F of the water plugging agent _r 。

Substituting equation (10) into equation (9) yields:

s520, obtaining the effective thickness H of the region to be injected with the agent and the porosity of the region to be injected with the agent

Due to the effective thickness h of each layer _i Is not influenced by FSG water shutoff agent, and the effective thickness of each layer is h _i The sum of (a) and (b) is the effective thickness H of the region to be injected is constant.

Obtaining the porosity of the region to be injected with the agent according to the established multilayer oil reservoir model

The porosity of the zone to be injected refers to the ratio of the sum of the pore volumes in the formation that are interconnected and allow fluid flow under normal pressure conditions to the total volume of the formation, expressed as a percentage.

S530, according to the residual resistivity F of the water shutoff agent _r The agent to be injectedThe effective thickness H of the area and the porosity of the area to be injected with the agent

And the acting radius r of the water shutoff agent _p And determining the dosage V of the water shutoff agent.

The calculation formula of the preset calculation model of the water shutoff agent dosage is as follows:

inputting the formula (11) into a model for calculating the dosage of the water shutoff agent, namely the formula (12), to obtain:

wherein V is the dosage of FSG sand control water shutoff agent, and the unit is m ³ (ii) a H is the effective thickness of the region to be injected, and the unit is m;

the porosity of the area to be injected with the agent; and (4) substituting actual field data into the water shutoff agent dosage calculation model to obtain the water shutoff agent dosage V, and determining the accurate dosage V of the water shutoff agent.

Furthermore, in order to make the usage amount V of the water shutoff agent predicted by the method for determining the usage amount of the water shutoff agent according to the embodiment of the present application more accurate and better fit with the water shutoff effect required by the oil well to be injected with the agent, an embodiment is further provided in the present application, and as shown in fig. 9, after determining the usage amount V of the water shutoff agent, the method further includes:

and S600, obtaining the performance evaluation result of the water shutoff agent.

And performing an indoor simulation water plugging operation test on the multilayer oil reservoir model according to the determined using amount V of the water plugging agent, and comparing the oil yield, the water content, the sand production rate and the damage rate to the formation core after the oil well is plugged with water with the parameters before the agent is injected into the oil well after the water plugging operation is completed to obtain a water plugging agent performance evaluation result.

And S700, acquiring an additional multiple F according to the performance evaluation result of the water shutoff agent.

Determination principle of additional multiple F: and obtaining a water plugging performance evaluation result according to an indoor test result, analyzing the sand production rate and the rock core damage rate of the oil well after water plugging operation, and combining the actual stratum permeability of the oil well after the water plugging operation, thereby obtaining the water plugging agent dosage V capable of balancing the rock core damage rate and the water plugging effect at the same time.

And S800, correcting the dosage V of the water shutoff agent through the dosage calculation model of the water shutoff agent according to the additional multiple F.

The formula of the corrected calculation model of the dosage of the water shutoff agent is as follows:

and correcting the model for calculating the dosage of the water shutoff agent by the additional multiple F according to the evaluation result of the performance of the water shutoff agent, thereby more scientifically and accurately determining the dosage V of the water shutoff agent which is basically consistent with the target oil well condition, obtaining a better water shutoff effect and further improving the oil yield of the oil well.

The working process and effect of the method for determining the dosage of the sand control water shutoff agent provided by the embodiment of the invention are described by specific examples.

The water shutoff agent of the embodiment of the application adopts FSG (flood-Sensitive Gel, vast diffuse Gel) sand control water shutoff agent, and has good sand control and selective water shutoff integrated capacity. The FSG is semisolid colloid, namely non-Newtonian fluid, which is formed by mutually connecting colloid particles, macromolecules or surfactant molecules into a net structure, and after the semisolid colloid enters a hypertonic layer in an agent injection area, the FSG sand control water plugging agent absorbs water and expands to plug pores in a stratum.

TABLE 1

TABLE 2

Table 1 shows production data before E10 water shutoff operation measures of a target well, and the current production of 152.6m of E10 well ³ D, 8.6m of daily oil ³ D, water content is 94.4%; the E10 well oil well parameter is the borehole radius r _w 0.1397m and a supply radius r _e Is 200 m; the E10 well formation parameters are shown in table 2.

As can be seen from the analysis of tables 1 and 2, the sand production phenomenon of the target well E10 gradually worsens, the water content is higher, the first small layer is a high permeability layer, the water absorption amount of the first small layer is about 62% of the water absorption amount of the whole well, and sand control and water plugging measures need to be carried out on the target well E10, so that the production efficiency of the oil well is improved.

Specifically, when the sand control and water plugging measure is performed on the E10 well by adopting the method for determining the water plugging agent consumption provided by the embodiment of the application, a multi-layer oil reservoir model needs to be established in advance, and the permeability difference of a plurality of small layers in the stratum is simulated by selecting different filling materials. And then carrying out an indoor test according to the test requirement, specifically simulating various dynamic states of the fluid moving in the oil well to obtain a plurality of dynamic data, thereby establishing a water shutoff agent dosage calculation model. And determining the dosage V of the water shutoff agent according to the dosage calculation model of the water shutoff agent, thereby determining sand control and water shutoff measures.

According to the indoor test, the expected effect coefficient M is determined to be 4, the residual resistance coefficient Fr of the water shutoff agent is determined to be 8.5, and the expected effect coefficient M and the residual resistance coefficient Fr of the water shutoff agent which are measured by the test are substituted into the formula (9) to obtain the radius r of the water shutoff agent reaching the stratum _p And was 2.54 m.

Obtaining the action radius r of the water plugging agent _p And then, calculating the dosage V of the water shutoff agent according to the dosage calculation model of the water shutoff agent.

After the dosage V of the water shutoff agent is determined, an indoor water shutoff performance test is carried out, and a water shutoff agent performance evaluation result is obtained according to an indoor test result, referring to the following table 3 and fig. 10:

TABLE 3

Sign of water shutoff agent	1	2	3	4	5
						Ko/mDc	1280	1310	1195	1250	1300
Ko’/mDc	1108	223	185	140	1040
						Injury rate/%)	2.8	83	84.5	88.8	34
Sand yield, g/l	0.03	0.82	0.22	0.6	5.38

Table 3 above shows the evaluation results of the performance of each plugging agent obtained after determining the amount of the plugging agent used for plugging the E10 well. In table 3, the code 1 of the water shutoff agent is FSG sand control water shutoff agent, 2 is phenol resin-formaldehyde-p-toluenesulfonic acid, 3 is epoxy resin-ethylenediamine, 4 is UP resin-methyl ethyl ketone peroxide, and 5 is cationic polyacrylamide, and the indoor water shutoff performance test method is performed according to SY/T6572 plus 2003 "resin performance evaluation method for sand control", so as to evaluate the core damage rate and sand control capability of different water shutoff agents.

The No. 2, 3 and 4 water shutoff agents are thermosetting resin sand control materials, can control sand production of oil wells, but have overlarge damage rate to rock cores; the No. 5 water shutoff agent is a water-soluble polymer material, and although the damage rate to the rock core is small, the sand consolidation capability is weak, and an ideal sand control water shutoff effect cannot be achieved. Therefore, the FSG sand control water shutoff agent is adopted, and the dosage of the FSG sand control water shutoff agent determined by the method for determining the dosage of the water shutoff agent can ensure the sand fixation capacity and reduce the damage rate to the rock core.

FIG. 10 is a schematic diagram of the plugging rates of the FSG sand-controlling plugging agent on the water layer and the oil layer at different temperatures, which shows the plugging rates of the FSG sand-controlling plugging agent on the water layer and the oil layer (oil core) at three temperatures of 30 ℃, 60 ℃ and 90 ℃ respectively at different processing capacities of the plugging agent; the upper three curves in the figure are the plugging rates of the water layer at different temperatures, and the lower three curves are the plugging rates of the oil layer at different temperatures. The plugging rate of the oil layer is used for representing the core damage rate of the FSG sand control water plugging agent to the target well, and is determined according to the ratio of the initial permeability of the core to the saturated oil core after the water plugging agent is injected. The plugging rate of the water layer is expressed as the plugging effect of the FSG sand control plugging agent on the target well. The treatment amount refers to the pore volume of the water plugging agent under different water plugging agent dosage, and the unit is PV (pore volume).

As can be seen from FIG. 10, when the treatment capacity of the FSG sand-controlling water shutoff agent is 1PV, the shutoff rate of the water layer is more than 55%; when the dosage of the FSG sand control water plugging agent is 4PV, the plugging rate of the water layer reaches 80 percent. The FSG sand control water plugging agent is proved to have obvious plugging effect on the oil well with high water content.

Continuing to refer to fig. 10, when the handling capacity of the oil layer is 1PV, the plugging rate of the saturated oil core is less than 3%; the plugging rate was about 12% at a throughput of 4 PV. The FSG sand control water shutoff agent is proved to have lower damage rate to the rock core in the oil well.

As can be seen from the above table 3 in combination with FIG. 10, when the treatment capacity of the FSG sand control water shutoff agent reaches 2PV, the sand production rate of the E10 well is reduced to be below 0.03%, and the additional times F and L are determined according to the evaluation result of the water shutoff performance and the highest value of the current permeability of the E10 well _p ＝Q _p The addition multiple F is 2.1, and the dosage V of the final FSG sand control water shutoff agent is 288m after the dosage of the water shutoff agent is corrected according to the addition multiple F ³ 。

Fig. 11 and table 4 are data and production graphs after water shutoff operation is performed on the E10 well after the dosage of the FSG sand control water shutoff agent is corrected, and as shown in fig. 11 and table 4, after FSG sand control water shutoff operation is performed on the E10 well, the water content of the E10 well is significantly reduced, the sand production rate is effectively controlled, and the oil production rate of the E10 well is increased.

TABLE 4

Table 4 is a table of production data from the E10 well production data curve of fig. 11 compared before and after FSG sand control water shutoff measures, where C1 is the daily fluid production curve, C2 is the water cut curve, C3 is the daily oil production curve, and the time at point P in the graph is the time to perform FSG sand control water shutoff operations on the E10 well. Compare the curves before and after the P pointThe rising and falling conditions of the wire show that after the FSG sand control water plugging operation is carried out on the E10 well, the daily production liquid of the E10 well is 272m3/d and the daily oil production is 23.5m ³ D, the water content is 91.5 percent, the water content of the well is obviously reduced (the water absorption of the first small layer accounts for about 23.2 percent of the water absorption of the whole well), the sand production is controlled, and the oil is increased by 10580.8m in an accumulated way ³ 。

According to the test results of the embodiment, the method for determining the dosage of the water shutoff agent is simple, and the dosage of the water shutoff agent is scientifically and accurately determined by considering various parameters, test results and performance evaluation results of the water shutoff agent in the area to be filled. The usage amount of the FSG sand control water shutoff agent obtained by the method for determining the usage amount of the water shutoff agent can meet the actual requirements of an oil well to be subjected to water shutoff operation, the sand control water shutoff effect of a high-water-content oil field is remarkable while the core damage rate is controlled, and the effect on the oil yield and the oil production quality of the oil well is obvious.

And moreover, the FSG sand control and water plugging agent is adopted, so that the sand control and water plugging integrated construction of the oil production well can be realized, and the operation time and the operation cost are saved. And the system can also realize the general injection and the immobile pipe column construction, is suitable for operating in a narrow space of an offshore platform, has a long sand control effective period and has a wide technical market prospect. The method for determining the using amount of the water plugging agent, which is provided by the embodiment of the application, enables offshore oil fields to have higher sand prevention strength and lower formation damage rate after the technology is applied, has good oil-water selective plugging capability, and has important guiding significance for reducing water content of oil wells and increasing oil content of extract.

According to another aspect of the embodiments of the present application, there is also provided a device for determining an amount of a water shutoff agent, as shown in fig. 12, the device including:

the model building module is used for determining an agent region to be injected according to the logging data and building a multi-layer oil reservoir model;

the post-injection flow rate determination module is used for determining the flow rate a of a first small layer after injection of the agent according to the multi-layer oil reservoir model, wherein the first small layer is the small layer with the highest permeability;

an expected effect coefficient determining module, configured to determine, according to the flow rate a and the second flow rate after the first small layer is injected with the water shutoff agenti flow rate f 'after the injection of the agent into the small layer' _i Determining the expected effect coefficient M of the water shutoff agent in the area to be injected;

a post-injection permeability determination module for determining the permeability K 'of the first small layer after injection according to the flow rate a of the first small layer after injection' ₁ ；

The water shutoff agent action radius determining module is used for determining the permeability K 'of the first small layer after the agent is injected according to the expected effect coefficient M of the water shutoff agent' ₁ Determining the action radius r of the water shutoff agent in the area to be injected by the Darcy radial flow equation _p ；

A water shutoff agent dosage determination module used for calculating a model according to the preset water shutoff agent dosage and the action radius r of the water shutoff agent _p And determining the dosage V of the water shutoff agent in the area to be injected.

The device for determining the dosage of the water shutoff agent is used for simulating the dynamic data of the stratum before and after the water shutoff operation of a target well by establishing a multilayer oil reservoir model, so that the determined dosage V of the water shutoff agent can be more fit with the actual water shutoff requirement of an oil well to be subjected to the water shutoff operation, and the water shutoff agent is prevented from being too large in dosage and causing waste when the water shutoff agent can achieve the preset effect.

Further, the determination of the dosage of the water shutoff agent further comprises: the evaluation result acquisition module is used for acquiring the performance evaluation result of the water shutoff agent after determining the dosage V of the water shutoff agent; the additional multiple obtaining module is used for obtaining an additional multiple F according to the performance evaluation result of the water shutoff agent; and the correction module is used for correcting the dosage V of the water plugging agent through the dosage calculation model of the water plugging agent according to the additional multiple F.

And carrying out an indoor simulation test on the water plugging agent dosage V determined by the water plugging agent dosage calculation model, and acquiring a water plugging agent performance evaluation result according to an indoor test result, so that the acquired additional multiple F corrects the water plugging agent dosage calculation model, the water plugging agent dosage V is determined more scientifically and accurately, a better water plugging effect is obtained, and the oil production is improved.

As shown in fig. 13, according to another aspect of the embodiments of the present application, there is provided an electronic apparatus including: at least one processor; and a memory and a communications component communicatively coupled to the at least one processor; the memory stores instructions executable by the at least one processor, and when the instructions are executed by the at least one processor, the instructions establish a data channel through the communication component, so that the at least one processor can execute the water shutoff agent usage determining method.

With continued reference to fig. 13, the electronic device of the embodiment of the present application further includes a processor (processor)901, a memory (memory)902, a communication Interface (Communications Interface)903, and a communication bus 504. Wherein: the processor 901, the communication interface 903, and the memory 902 communicate with each other via the communication bus 504. A communication interface 903 for communicating with network elements of other devices, such as clients or other servers. The processor 901 is configured to execute the program 905, and may specifically execute the relevant steps in the foregoing method for determining the usage amount of the water shutoff agent. Specifically, the program 905 may include a program code including computer-executable instructions for executing the water shutoff agent usage amount determination method proposed in the above embodiment.

The processor 901 may be a central processing unit CPU, or an application Specific Integrated circuit asic, or one or more Integrated circuits configured to implement embodiments of the present application. The one or more processors included in the mobile terminal and/or the inspection tool may be the same type of processor, such as one or more CPUs; or may be different types of processors such as one or more CPUs and one or more ASICs.

The memory 902 stores a program 905. Memory 902 may comprise high-speed RAM memory, and may also include non-volatile memory (non-volatile memory), such as at least one disk memory.

According to another aspect of the embodiments of the present application, a non-transitory computer-readable storage medium is provided, where the computer-readable storage medium stores computer-executable instructions for causing a computer to execute the foregoing method for determining an amount of a water shutoff agent.

The algorithms or displays presented herein are not inherently related to any particular computer, virtual system, or other apparatus. Various general purpose systems may also be used with the teachings herein. The required structure for constructing such a system will be apparent from the description above. In addition, embodiments of the present application are not directed to any particular programming language. It will be appreciated that a variety of programming languages may be used to implement the teachings of the present application as described herein, and any descriptions of specific languages are provided above to disclose the best modes of the present application.

In the description provided herein, numerous specific details are set forth. However, it is understood that embodiments of the application may be practiced without these specific details. In some instances, well-known methods, structures and techniques have not been shown in detail in order not to obscure an understanding of this description.

Similarly, it should be appreciated that in the foregoing description of exemplary embodiments of the application, various features of the embodiments of the application are sometimes grouped together in a single embodiment, figure, or description thereof for the purpose of streamlining the application and aiding in the understanding of one or more of the various inventive aspects. However, the disclosed method should not be construed to reflect the intent: this application is intended to cover such departures from the present disclosure as come within known or customary practice in the art to which this invention pertains.

Those skilled in the art will appreciate that the modules in the device in an embodiment may be adaptively changed and disposed in one or more devices different from the embodiment. The modules or units or components of the embodiments may be combined into one module or unit or component, and may be divided into a plurality of sub-modules or sub-units or sub-components. All of the features disclosed in this specification (including any accompanying claims, abstract and drawings), and all of the processes or elements of any method or apparatus so disclosed, may be combined in any combination, except combinations where at least some of such features and/or processes or elements are mutually exclusive. Each feature disclosed in this specification (including any accompanying claims, abstract and drawings) may be replaced by alternative features serving the same, equivalent or similar purpose, unless expressly stated otherwise.

It should be noted that the above-mentioned embodiments illustrate rather than limit the application, and that those skilled in the art will be able to design alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses shall not be construed as limiting the claim. The word "comprising" does not exclude the presence of elements or steps not listed in a claim. The word "a" or "an" preceding an element does not exclude the presence of a plurality of such elements. The application may be implemented by means of hardware comprising several distinct elements, and by means of a suitably programmed computer. In the unit claims enumerating several means, several of these means may be embodied by one and the same item of hardware. The usage of the words first, second and third, etcetera do not indicate any ordering. These words may be interpreted as names. The steps in the above embodiments should not be construed as limited to the order of execution unless otherwise specified.

Finally, it should be noted that: the limitations of the steps involved in the present application are not considered to limit the order of the steps on the premise of not affecting the implementation of the specific embodiments, and the steps written in the foregoing may be executed in advance, may be executed later, or may even be executed simultaneously, so long as the present solution can be implemented, all the steps should be regarded as belonging to the protection scope of the present application.

The above embodiments are only used to illustrate the technical solutions of the present application, and not to limit the same; although the present application has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art will understand that: the technical solutions described in the foregoing embodiments may still be modified, or some or all of the technical features may be equivalently replaced; such modifications and substitutions do not depart from the spirit and scope of the present disclosure, and the present disclosure should be construed as being covered by the claims and the specification. In particular, the technical features mentioned in the embodiments can be combined in any way as long as there is no structural conflict. The present application is not intended to be limited to the particular embodiments disclosed herein, but rather to cover all embodiments falling within the scope of the appended claims.

Claims

1. A method for determining the dosage of a water shutoff agent is characterized in that a multi-layer reservoir model of an agent region to be injected is predetermined, the multi-layer reservoir model comprises n small layers with different permeability, and the method comprises the following steps:

wherein i is more than or equal to 2 and less than or equal to n;

according to the flow dividing rate a after the first small layer is injected with the agent, determining the permeability K 'after the first small layer is injected with the agent' ₁ ；

According to the expected effect coefficient M of the water shutoff agent and the permeability K 'of the first small layer after agent injection' ₁ Determining the action radius r of the water shutoff agent in the area to be injected by the Darcy radial flow equation _p ；

2. The method for determining the dosage of the water shutoff agent according to claim 1, wherein the flow splitting ratio f 'after the ith small layer of the injection agent' _i Is determined by the following steps:

3. The method for determining the usage amount of the water shutoff agent according to claim 1, wherein after the water shutoff agent is injected into the agent region to be injected, the first small layer comprises a water shutoff region and an outer region; the determination of the permeability K 'of the first small layer after injection' ₁ The method comprises the following steps:

Obtaining the oil well borehole radius r of the multilayer oil reservoir model _w Oil well supply radius r _e Pressure difference Deltap between well bottom and stratum, and viscosity of stratum water mu _w And the skin factor S of the reservoir;

according to the permeability K of the water plugging area _1g And permeability K of said outer zone ₁ The radius r of the oil well borehole _w The oil well supply radius r _e Pressure difference Δ p between the bottom of the well and the formation, and viscosity μ of the formation water _w And the skin coefficient S of the reservoir, and determining the permeability K 'of the first small layer after injection' ₁ 。

4. The method for determining the amount of the plugging agent according to claim 3, wherein a model is calculated according to a preset amount of the plugging agent and the action radius r of the plugging agent _p Determining the dosage V of the water shutoff agent in the area to be injected with the agent, comprising the following steps:

According to the residual resistivity F of the water plugging agent _r Effective thickness H of the region to be injected and porosity of the region to be injected

And the action radius r of the water shutoff agent _p And determining the dosage V of the water shutoff agent.

5. The method for determining the dosage of the water shutoff agent according to claim 1, wherein after determining the dosage V of the water shutoff agent in the region to be injected, the method further comprises:

obtaining the performance evaluation result of the water shutoff agent;

6. The method for determining the dosage of the water shutoff agent according to claim 5, wherein the evaluation result of the performance of the water shutoff agent comprises a sand production rate and a core damage rate, and the obtaining of the additional multiple F comprises:

7. A device for determining a usage amount of a water shutoff agent, the device comprising:

an expected effect coefficient determining module for determining the flow splitting rate a ' of the first small layer injected with the water shutoff agent and the flow splitting rate f ' of the ith small layer injected with the agent according to the flow splitting rate a of the first small layer injected with the water shutoff agent and the flow splitting rate f ' _i Determining the expected effect coefficient M of the water shutoff agent in the area to be injected;

A water shutoff agent dosage determination module used for calculating a model according to the preset water shutoff agent dosage and the water shutoff agent action radius r _p And determining the dosage V of the water shutoff agent in the area to be injected.

8. The device for determining the amount of plugging agent according to claim 7, further comprising:

the evaluation result acquisition module is used for acquiring the performance evaluation result of the water shutoff agent after determining the dosage V of the water shutoff agent;

the additional multiple acquisition module is used for acquiring an additional multiple F according to the performance evaluation result of the water shutoff agent;

and the correction module is used for correcting the dosage V of the water plugging agent through the dosage calculation model of the water plugging agent according to the additional multiple F.

9. An electronic device, comprising:

at least one processor; and the number of the first and second groups,

a memory and a communication component communicatively coupled to the at least one processor; wherein,

the memory stores instructions executable by the at least one processor to establish a data channel through a communication component to enable the at least one processor to perform the method of any one of claims 1-6 when executed by the at least one processor.

10. A non-transitory computer-readable storage medium having stored thereon computer-executable instructions for causing a computer to perform the method of any one of claims 1-6.