阅读说明：本技术 确定油藏开发过程中孔吼半径的方法 (Method for determining pore roar radius in oil reservoir development process ) 是由 孙建 何娇娇 马瑞 王庆魁 季岭 吕中锋 赵常 韩璞 苑吉波 张传干 王飞 李 于 2019-08-21 设计创作，主要内容包括：本发明公开了一种确定油藏开发过程中孔吼半径的方法,属于石油天然气开采领域。在钻井过程中,获取目标区域中不同位置的岩石；检测所述目标区域中不同位置的岩石的孔吼半径和渗透率；基于所述目标区域中不同位置的岩石的孔吼半径和渗透率,确定孔吼半径与渗透率的关系公式；在所述目标区域的采油过程中,检测所述目标区域的目标井的目标层中的目标小层处的测井参数；基于所述测井参数,确定所述目标小层的岩石的目标渗透率；基于所述目标渗透率和所述关系公式,确定所述目标小层的岩石的目标孔吼半径。采用本申请,可以有效解决相关技术中缺乏一种确定油藏开发过程中孔吼半径的方法的技术问题。(The invention discloses a method for determining the hole roar radius in the oil reservoir development process, and belongs to the field of oil and gas exploitation. In the drilling process, obtaining rocks at different positions in a target area; detecting the croup radius and permeability of rocks at different positions in the target region; determining a relational formula of the bore radius and the permeability based on the bore radius and the permeability of rocks at different positions in the target area; detecting logging parameters at a target sub-layer in a target layer of a target well of the target zone during oil production of the target zone; determining a target permeability of rock of the target small layer based on the logging parameters; and determining the target hole roar radius of the target small layer of rock based on the target permeability and the relational formula. By adopting the method and the device, the technical problem that a method for determining the hole roar radius in the oil reservoir development process is lacked in the related technology can be effectively solved.)

1. A method of determining the pore roar radius during reservoir development, the method comprising:

in the drilling process, obtaining rocks at different positions in a target area;

detecting the croup radius and permeability of rocks at different positions in the target region;

determining a relational formula of the bore radius and the permeability based on the bore radius and the permeability of rocks at different positions in the target area;

detecting logging parameters at a target sub-layer in a target layer of a target well of the target zone during oil production of the target zone;

determining a target permeability of rock of the target small layer based on the logging parameters;

and determining the target hole roar radius of the target small layer of rock based on the target permeability and the relational formula.

2. The method of claim 1, wherein the target well is a production well or a water injection well of the target area.

3. The method of claim 1, wherein determining a formula of a croup radius versus permeability based on a croup radius and permeability of rock at different locations in the target region comprises:

and performing curve fitting based on the croup radius and the permeability of the rocks at different positions in the target area to obtain a relational formula of the croup radius and the permeability.

4. The method of claim 1, wherein the logging parameters comprise acoustic time difference and deep induction resistivity.

5. The method of claim 3, wherein determining the target permeability of the rock of the target sub-layer based on the logging parameters comprises:

according to the acoustic wave time difference value and the deep induction resistivity, the target permeability of the rock of the target small layer utilizes the following formula:

wherein Δ t is represented as a sound wave time difference value, R, of the target small layer_tDeep induced current represented as said target small layerResistivity, K, is expressed as the target permeability of the rock of the target small layer.

6. The method of claim 1, wherein the logging parameter comprises an acoustic wave time difference.

7. The method of claim 5, wherein determining the target permeability of the rock of the target sub-layer based on the logging parameters comprises:

obtaining core porosity P corresponding to the target small layer according to the acoustic wave time difference value, wherein the core porosity is calculated by using the following formula:

P＝0.1927R_t ^-35.42；

according to the core porosity P being less than or equal to 18%, calculating the target permeability of the rock of the target small layer by using the following formula:

K＝0.0158e^0.3451×P；

according to the core porosity P being more than 18%, the target permeability of the rock of the target small layer is calculated by using the following formula:

K＝0.0474e^0.3451×P；

wherein K represents the target permeability of the rock of the target small layer.

8. The method of claim 1, wherein the logging parameters include acoustic wave time difference values and natural gamma ray relative values.

9. The method of claim 7, wherein determining the target permeability of the rock of the target sub-layer based on the logging parameters comprises:

obtaining the porosity phi corresponding to the target small layer according to the acoustic wave time difference value, wherein the porosity is calculated by using the following formula:

P＝0.1927R_t ^-35.42；

obtaining core porosity P corresponding to the target small layer according to the porosity, wherein the core porosity is calculated by using the following formula:

Φ＝1.5101P-1.2704；

obtaining the core shale content sh corresponding to the target small layer according to the natural gamma relative value, wherein the core shale content is calculated by using the following formula:

sh＝7.915e^1.82GR；

according to the core porosity and the core mud content, the target permeability of the rock of the target small layer utilizes the following formula:

lgK＝-3.95+1.28lgsh+5.5LgΦ；

wherein K represents the target permeability of the rock of the target small layer.

10. The method of claim 1, further comprising:

and drawing a position diagram of the target wells of the target small layer, and marking a target hole roar radius corresponding to each target well in the position diagram.

Technical Field

The invention relates to the technical field of reservoir development, in particular to a method for determining the hole roar radius in the reservoir development process.

Background

Because the reservoir of the continental facies sandstone reservoir is influenced by the deposition effect in ancient times, the bore radius of the reservoir and the permeability of the reservoir change rapidly in the longitudinal direction and the transverse direction. In the process of reservoir water injection development, water injection is often flushed along a high-permeability strip, so that the radius of a pore of a high-permeability layer is increased, interlayer and plane heterogeneity is enhanced, and the reservoir development effect is poor. Therefore, the change rule of the pore roar radius in the oil reservoir development process is determined, a method for quantitatively representing the pore roar radius is provided for developing the oil reservoir with high permeability zone development in the middle and later stages, and the method has certain guiding significance for improving the profile control and flooding effect and improving the oil reservoir recovery efficiency.

In the course of implementing the present application, the inventors found that the related art has at least the following problems:

currently, there is a lack in the related art of a method for determining the pore roar radius during reservoir development.

Disclosure of Invention

In order to solve the technical problems in the related art, the embodiment of the application provides a method for determining the hole roar radius in the reservoir development process. The technical scheme of the method for extracting the core lyrics of the song is as follows:

in one aspect, a method for determining a bore radius during reservoir development is provided, the method for determining the bore radius during reservoir development comprising:

obtaining rocks at different positions in a target area through coring;

detecting the croup radius and permeability of rocks at different positions in the target region;

determining a relational formula of the bore radius and the permeability based on the bore radius and the permeability of rocks at different positions in the target area;

detecting logging parameters at a target sub-layer in a target layer of a target well of the target zone during oil production of the target zone;

determining a target permeability of rock of the target small layer based on the logging parameters;

and determining the target hole roar radius of the target small layer of rock based on the target permeability and the relational formula.

Optionally, the target well is an oil well or a water well of the target area.

Optionally, the determining a relational formula of a throat radius and a permeability based on the throat radius and the permeability of the rock at different positions in the target region includes:

and performing curve fitting based on the croup radius and the permeability of the rocks at different positions in the target area to obtain a relational formula of the croup radius and the permeability.

Optionally, the logging parameters include an acoustic wave time difference value and a deep induction resistivity.

Optionally, the determining the target permeability of the rock of the target small layer based on the logging parameter includes:

where Δ t is expressed as the acoustic time difference, R_tExpressed as deep induction resistivity and K as permeability.

Optionally, the logging parameter includes an acoustic wave time difference value.

Optionally, the determining the target permeability of the rock of the target small layer based on the logging parameter includes:

and obtaining the porosity P corresponding to the target small layer according to the acoustic wave time difference value, wherein the porosity is calculated by using the following formula:

P＝0.1927R_t ^-35.42；

according to the porosity P is less than or equal to 18%, the target permeability of the rock of the target small layer is calculated by the following formula:

K＝0.0158e^0.3451×P；

according to the porosity P > 18%, the target permeability of the rock of the target small layer is calculated using the formula:

K＝0.0474e^0.3451×P；

wherein K represents the target permeability of the rock of the target small layer.

Optionally, the logging parameters include acoustic wave time difference values and natural gamma relative values.

Optionally, the determining the target permeability of the rock of the target small layer based on the logging parameter includes:

and obtaining the porosity P corresponding to the target small layer according to the acoustic wave time difference value, wherein the porosity is calculated by using the following formula:

P＝0.1927R_t ^-35.42；

obtaining core porosity phi corresponding to the target small layer according to the porosity, wherein the core porosity is calculated by using the following formula:

Φ＝1.5101P-1.2704；

obtaining the core shale content sh corresponding to the target small layer according to the natural gamma relative value, wherein the core shale content is calculated by using the following formula:

sh＝7.915e^1.82GR；

according to the core porosity and the core mud content, the target permeability of the rock of the target small layer utilizes the following formula:

lgK＝-3.95+1.28lgsh+5.5LgΦ；

wherein K represents the target permeability of the rock of the target small layer.

Optionally, the method further includes:

and drawing a position diagram of the target wells of the target small layer, and marking a target hole roar radius corresponding to each target well in the position diagram.

The beneficial effects brought by the technical scheme provided by the embodiment of the application at least comprise:

according to the method provided by the embodiment of the application, the method can be used for obtaining the relational formula of the croup radius and the permeability based on the analysis of the coring well data, obtaining the permeability of the target stratum of the target well by the logging data, and further obtaining the croup radius of the target stratum of the target well. The method provided by the embodiment of the application provides a method for determining the hole roar radius in the oil reservoir development process, so that the hole roar radius in the oil reservoir development process is determined.

Drawings

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

FIG. 1 is a flow chart of a method for determining the bore radius during reservoir development according to an embodiment of the present invention;

FIG. 2 is a plot of the throat radius of any small layer of a fault block at the beginning of development according to an embodiment of the present invention;

FIG. 3 is a plot of the throat radius of any one sub-layer of a fault block during development, according to an embodiment of the present invention;

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

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.

The embodiment of the application provides a method for determining a pore roar radius in an oil reservoir development process, and the method can be used for obtaining a relational formula of the pore roar radius and permeability based on the analysis of coring well data, obtaining the permeability of a target small layer of a target well by logging data, and obtaining the pore roar radius of the target small layer of the target well.

The method provided by the embodiment of the application can be applied to the technical field of oil extraction engineering, and is particularly used for determining the hole roar radius in the oil reservoir development process. The specific method for determining the potential dispersity of the oil reservoir seepage field comprises the steps of firstly, acquiring the croup radius and the permeability of rocks at different positions in a target area through coring data in a drilling process, then, determining a relational formula of the croup radius and the permeability, then, determining the target permeability of the rocks of a target small layer based on logging parameters of the rocks of the target small layer in the target layer of a target well of the target area, and finally, determining the target croup radius of the rocks of the target small layer based on the target permeability and the relational formula. After the target croup radius of the target small layer of rock is determined, the mining work of the target oil reservoir can be guided according to the obtained change rule of the croup radius of the target small layer, for example, the larger croup radius is blocked.

In step 1, rocks at different locations in the target area are acquired by coring.

Wherein the target area may be a fault block comprising at least one coring well. The core well is a well drilled by using a core drill bit and a core drilling tool, and mainly aims to drill an underground core and directly obtain various data or parameters of lithology, lithofacies, physical properties, crude oil, oil content and the like of rocks at the corresponding position of the core through chemical experiments. The core is a cylindrical rock sample taken from the pore space using a ring core drill and other coring tools.

In practice, in a target area, a core is drilled underground based on a coring bit, rocks at different positions are obtained based on the core, and the rocks are chemically analyzed to determine various data or parameters of lithology, lithofacies, physical properties, oil production, oil content and the like of the rocks at different positions, wherein the parameters can comprise a croup radius and permeability.

In step 2, the bore radius and permeability of rock at different locations in the target zone are detected.

The croup is a gap between the underground rocks, and the croup radius can represent the size of the gap between the underground rocks.

In the implementation, the croup radius and the permeability of the rock at different positions are obtained based on various data or parameters such as lithology, lithofacies, physical properties, oiliness and oiliness of the rock at different positions.

In step 3, a formula of the relationship between the bore radius and the permeability is determined based on the bore radius and the permeability of the rock at different positions in the target area.

In implementation, the formula of the relationship between the croup radius and the permeability in the target region can be determined through the croup radius and the permeability of rocks at different positions in the region.

Optionally, curve fitting may be performed based on the croup radius and the permeability of the rock at different positions in the target region, so as to obtain a relational formula between the croup radius and the permeability.

In implementation, based on the throat radius and the permeability of rocks at different positions in the target area, the permeability and the throat radius can be input into mapping software, the permeability is used as an abscissa, the throat radius is used as an ordinate, a scatter diagram is made, data points in the scatter diagram are analyzed, the relationship between the throat radius and the permeability is determined, and a relational formula between the throat radius and the permeability is fitted.

In step 4, logging parameters at a target sub-layer in a target layer of a target well of the target zone are detected during oil production of the target zone.

Wherein, the target well can be an oil well or a water well of the target area.

In the implementation, the well wall is measured at intervals from the well head, and data corresponding to parameters such as the acoustic wave time difference value, the deep induction resistivity and the porosity of the rock stratum are obtained. And taking the data of different parameters as an abscissa and the measured distance as an ordinate to prepare a scatter diagram, and connecting the data on the scatter diagram to obtain curves corresponding to the different parameters respectively, namely logging curves.

The marking layer is a rock stratum unit with obvious marks and stable distribution, and small layers can be further divided according to the comparison between the rock stratum and the marking layer.

In the implementation, a logging tool is used for detecting at least one well, data corresponding to parameters such as the time difference of sound waves, the deep induction resistivity and the porosity of a rock stratum are obtained, the data of different parameters are used as abscissa, the measured distance is used as ordinate, a scatter diagram is made, the data on the scatter diagram are connected, curves corresponding to different parameters are obtained, parts with obvious response characteristics in the curves are determined, the parts corresponding to the rock stratum are used as a mark layer, and the characteristics of rocks in the mark layer are recorded.

Further, the interval is divided according to the deposition cycle characteristics of the rock, and a target layer is obtained, wherein the deposition cycle characteristics of the rock can be obtained in a well logging curve. In the target layer, the target layer is divided based on the characteristics of the rocks of at least one marker layer, and small layers of the target layer are obtained.

It should be noted that the part with obvious response characteristics in some parameter curves may be special lithologic rock formations such as oil shale, carbonate rock, and chemical rock layer, and these special lithologic rock formations are marked clearly and distributed stably and can be used as marking layers.

Optionally, the logging parameters may be the time difference of the acoustic waves and the deep induction resistivity.

In practice, the permeability of the target sub-layer of the target zone of the target well is calculated using the following formula:

where Δ t is expressed as the acoustic time difference, R_tExpressed as deep induction resistivity and K as permeability.

The unit of permeability is 10^-3μm²。

Optionally, the logging parameter comprises an acoustic wave time difference value.

In the implementation, according to the difference value in the acoustic wave time, the core porosity P corresponding to the target small layer is obtained, and the core porosity is calculated by using the following formula:

P＝0.1927R_t ^-35.42；

calculating the target permeability of the rock of the target small layer by using the following formula according to the core porosity P less than or equal to 18 percent:

K＝0.0158e^0.3451×P；

according to the core porosity P > 18%, the target permeability of the rock of the target small layer is calculated by using the following formula:

K＝0.0474e^0.3451×P；

where K represents the target permeability of the rock of the target small layer.

Optionally, the logging parameters include acoustic wave time difference values and natural gamma relative values.

The unit of permeability is 10^-3μm²。

In implementation, according to the difference in the acoustic wave time, the porosity Φ corresponding to the target small layer is obtained, and the porosity is calculated by using the following formula:

P＝0.1927R_t ^-35.42；

obtaining the core porosity P corresponding to the target small layer according to the porosity, wherein the core porosity is calculated by using the following formula:

Φ＝1.5101P-1.2704；

obtaining the core shale content sh corresponding to the target small layer according to the natural gamma relative value, wherein the core shale content is calculated by the following formula:

sh＝7.915e^1.82GR；

the target permeability of the rock of the target small bed is based on core porosity and core mud content using the following formula:

lgK＝-3.95+1.28lgsh+5.5LgΦ；

where K represents the target permeability of the rock of the target small layer.

The unit of the natural gamma relative value is API, and the unit of the permeability is 10^-3μm²。

It should be noted that there are many methods for calculating permeability based on well-logging data, and three of the methods are described herein, wherein the third method is a method summarized based on rock characteristics in the target region, and the calculation result is more accurate than the first two methods.

In step 6, a target bore radius of the target sub-layer of rock is determined based on the target permeability and the relational formula.

In implementation, the target permeability of the target sublayer is substituted into the relational formula, and the target croup radius of the target sublayer is obtained.

Optionally, a map of the target subzone's throat radius may be drawn based on data of the target subzone's target throat radius obtained, so that a change of the target subzone's throat radius may be observed more intuitively. The specific steps are as follows, drawing a position diagram of the target wells of the target small layer, and marking the target croup radius of the small layer of each target well in the position diagram.

The target well can be any well in the block, and the target small layer can be the same small layer of any well in the block.

In implementation, possible values of the throat radius in the block are divided into a plurality of sections, different sections correspond to different colors, the position of a target well is determined, the target well is marked, the throat radius of a target sublayer of the target well is determined, the section corresponding to the throat radius is determined, the color corresponding to the section is obtained, the target sublayer of the target well is marked by using the color, and a throat radius map of any sublayer is drawn.

Further, the croup radius map of any small layer can be divided based on the period. The croup radius distribution of a small layer at the initial stage of oil production of a block, see fig. 1, and the croup radius distribution of a small layer at the present stage of a block, see fig. 2, wherein different degrees of shading represent different colors.

Furthermore, according to the distribution diagram of the roar radius of the same subzone in different periods, the changing situation of the roar radius of the same subzone can be known more intuitively, for example, which zone of a fault block changes the fastest in the same time period. It can also be more intuitively understood that certain areas within the block have a bore-roar radius that needs to be blocked.

Further, a current hole roar radius distribution map of a certain small layer can be determined, a region with a hole roar radius exceeding a threshold value is determined, the hole roar radius of a plurality of wells in the region exceeds the threshold value, and the hole roar radius of the region is blocked. Selecting a blocking agent according to the bore radius of the region, putting the blocking agent into each well of the region, for example, according to an ion depth profile control agent, a pre-intersection face particle profile control agent and the like, and blocking the bore radius larger than a threshold value in the region.

Furthermore, a large amount of water and a plugging agent are injected into any well in the area, the plugging agent flows to a high-permeability layer along with water, the radius of the bore of the high-permeability layer is large, the blocking agent can block the radius of the bore of the high-permeability layer, after plugging is carried out, water is injected into the area, the water does not wash the high-permeability layer any more, but washes the low-permeability layer, and therefore oil in the low-permeability layer is collected.

The application embodiment provides a method for determining a pore roar radius in an oil reservoir development process, and the method can be used for obtaining a relational formula of the pore roar radius and permeability based on the analysis of coring well data, obtaining the permeability of a target small layer of a target well through logging data, and obtaining the pore roar radius of the target small layer.

The method provided by the embodiment of the application can be applied to the technical field of oil extraction engineering, and is particularly used for determining the hole roar radius in the oil reservoir development process. The specific method for determining the potential dispersity of the oil reservoir seepage field comprises the steps of firstly, obtaining the croup radius and the permeability of rocks at different positions in a target area through coring data, then, determining a relational formula of the croup radius and the permeability, then, determining the target permeability of the rocks of a target small layer based on logging parameters of the rocks of the target small layer in the target layer of a target well of the target area, and finally, determining the target croup radius of the rocks of the target small layer based on the target permeability and the relational formula. After the target croup radius of the rock of the target small layer is determined, the mining work of the target oil reservoir can be guided according to the obtained change rule of the target small layer, for example, the larger croup radius is blocked.

Fig. 4 is a schematic structural diagram of a computer device 400 according to an embodiment of the present invention, where the computer device 400 may generate a relatively large difference due to different configurations or performances, and may include one or more processors (CPUs) 401 and one or more memories 402, where the memory 402 stores at least one instruction, and the at least one instruction is loaded and executed by the processor 401 to implement the method according to the above-described each reservoir flow field control method embodiment. Certainly, the computer device may further have components such as a wired or wireless network interface, a keyboard, and an input/output interface, so as to perform input and output, and the computer device may further include other components for implementing the functions of the device, which is not described herein again.

In an exemplary embodiment, a computer-readable storage medium, such as a memory, including instructions executable by a processor in a computer device to perform the reservoir flow field regulation method of the above embodiments is also provided. For example, the computer-readable storage medium may be a Read-Only Memory (ROM), a Random Access Memory (RAM), a Compact Disc Read-Only Memory (CD-ROM), a magnetic tape, a floppy disk, an optical data storage device, and the like.

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, and the program may be stored in a computer-readable storage medium, and the storage medium may be a read-only memory, a magnetic disk or an optical disk.

The above description is only exemplary of the present invention and should not be taken as limiting the invention, as any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.