Reservoir stimulation method, device and storage medium

Abstract

An embodiment of the present application provides a reservoir stimulation method, device, and storage medium. In this method, when performing ball stimulation on a reservoir, multiple perforation intervals of the target well reservoir and the perforation parameters of each perforation interval are determined; according to the perforation parameters of the first perforation interval, completion fluid is pumped into the first perforation interval, and the first bottom hole pressure of the target well reservoir sent by a pressure acquisition device is received; during the process of controlling the pumping of multiple soluble temporary plugging balls into the first perforation interval, the second bottom hole pressure of the target well reservoir sent by the pressure acquisition device is received; the temporary plugging state of the soluble temporary plugging balls is determined according to the first bottom hole pressure and the second bottom hole pressure, so as to stimulate the reservoir. The present application accurately determines the temporary plugging state of the soluble temporary plugging balls by collecting the bottom hole pressure of the well reservoir in real time through the pressure acquisition device, thereby improving the efficiency of reservoir stimulation.

Description

Technical Field

[0001] The present application relates to the technical field of oil and gas exploitation, and particularly relates to a reservoir stimulation method, device, and storage medium. Background Art

[0002] Due to its many applications in aspects such as transportation, calorific value, and environment, the proportion of oil and gas in the world energy structure has been gradually increasing, and it has become an indispensable part of production and life. At present, higher requirements have been put forward for the exploration and exploitation of oil and gas. As an important production-increasing method, reservoir stimulation can improve the production of a single well through certain technological measures. The methods of reservoir stimulation mainly include two types: mechanical layered and segmented stimulation and non-mechanical layered and segmented stimulation. Among them, the ball-drop temporary plugging layered and segmented stimulation plays an extremely important role in non-mechanical layered and segmented stimulation.

[0003] In the prior art, when the reservoir is stimulated by the ball-drop layered and segmented stimulation technology, for the formation sections with relatively low in-situ stress and good physical properties, the completion fluid is first pumped. During the process of pumping the completion fluid, the pumping displacement is continuously increased until the displacement of the completion fluid required for the preset perforation section is reached; then, based on human experience, the relationship between the bottom-hole pressure of the perforation section and the pumped completion fluid is determined, and when to start dropping the ball and when to end dropping the temporary plugging ball is determined; after ending the dropping of the temporary plugging ball, the pumping displacement of the completion fluid is continuously increased until the displacement of the completion fluid required to fracture the second formation section is reached; thereafter, the ball-drop temporary plugging stimulation is repeatedly carried out layer by layer, so as to realize the stimulation of the entire well reservoir.

[0004] However, this method is blind, unable to determine which perforation section the injected temporary plugging ball plugs, nor can it determine the temporary plugging state of the perforation section, resulting in low efficiency of reservoir stimulation. Summary of the Invention

[0005] The embodiments of the present application provide a reservoir stimulation method, device, and storage medium, which can accurately judge the temporary plugging state of the soluble temporary plugging ball for the perforation section during reservoir stimulation, and improve the efficiency of reservoir stimulation.

[0006] In a first aspect, the embodiments of the present application provide a reservoir stimulation method, which includes:

[0007] Determine multiple perforation sections of the reservoir of the target well and the perforation parameters of each perforation section, where the perforation parameters include the length of the perforation section and the number of perforations.

[0008] According to the perforation parameters of the first perforation section among the multiple perforation sections, pump the completion fluid into the first perforation section, and receive the first bottom-hole pressure of the reservoir of the target well sent by the pressure acquisition device in the reservoir of the target well.

[0009] Control the pumping of a plurality of soluble temporary plugging balls into the first perforation section, and receive the second bottom hole pressure of the target well reservoir sent by the pressure acquisition device.

[0010] Determine the temporary plugging state of the soluble temporary plugging balls according to the first bottom hole pressure and the second bottom hole pressure, so as to transform the reservoir.

[0011] In a possible implementation manner, the determining the temporary plugging state of the soluble temporary plugging balls according to the first bottom hole pressure and the second bottom hole pressure includes:

[0012] Determine the fracture pressure of the first perforation section according to the first bottom hole pressure.

[0013] Judge whether the second bottom hole pressure is greater than the fracture pressure.

[0014] If the second bottom hole pressure is greater than or equal to the fracture pressure, it is determined that the soluble temporary plugging balls are successfully temporarily plugged.

[0015] If the second bottom hole pressure is less than the fracture pressure, it is determined that the soluble temporary plugging balls are temporarily plugged unsuccessfully.

[0016] In a possible implementation manner, the determining the fracture pressure of the first perforation section according to the first bottom hole pressure includes:

[0017] Control the continuous increase of the pumping displacement of the completion fluid, and the first bottom hole pressure changes with the change of the pumping displacement.

[0018] When it is determined that the first bottom hole pressure has an inflection point, determine the first bottom hole pressure corresponding to the inflection point as the fracture pressure of the first perforation section.

[0019] In a possible implementation manner, the method further includes:

[0020] If the soluble temporary plugging balls are temporarily plugged unsuccessfully, pump a plurality of soluble temporary plugging balls into the first perforation section again, and receive the third bottom hole pressure of the target well reservoir sent by the pressure acquisition device until the third bottom hole pressure is greater than or equal to the fracture pressure.

[0021] In a possible implementation manner, the method further includes:

[0022] When it is determined that the first bottom hole pressure has an inflection point, reduce the pumping displacement of the completion fluid to a preset displacement.

[0023] In a possible implementation manner, the determining the multiple perforation sections of the target well reservoir and the perforation parameters of each perforation section includes:

[0024] Obtain the in-situ stress of the reservoir of the target well.

[0025] Determine the plurality of perforation intervals and the perforation parameters of each perforation interval according to the magnitudes of the principal stresses in the in-situ stress.

[0026] In a second aspect, an embodiment of the present application provides a reservoir stimulation device, and the device includes:

[0027] A determination unit, configured to determine a plurality of perforation intervals of the reservoir of the target well and the perforation parameters of each perforation interval, where the perforation parameters include the length of the perforation interval and the number of perforations;

[0028] A processing unit, configured to pump completion fluid into the first perforation interval according to the perforation parameters of the first perforation interval among the plurality of perforation intervals;

[0029] A receiving unit, configured to receive the first bottom-hole pressure of the reservoir of the target well sent by a pressure acquisition device in the reservoir of the target well;

[0030] The processing unit is further configured to control the pumping of a plurality of soluble temporary plugging balls into the first perforation interval;

[0031] The receiving unit is further configured to receive the second bottom-hole pressure of the reservoir of the target well sent by the pressure acquisition device;

[0032] The determination unit is further configured to determine the temporary plugging state of the soluble temporary plugging balls according to the first bottom-hole pressure and the second bottom-hole pressure, so as to stimulate the reservoir.

[0033] In a possible implementation manner, the determination unit is specifically configured to determine the fracture pressure of the first perforation interval according to the first bottom-hole pressure; and determine whether the second bottom-hole pressure is greater than the fracture pressure; if the second bottom-hole pressure is greater than or equal to the fracture pressure, it is determined that the soluble temporary plugging balls are successfully temporarily plugged; if the second bottom-hole pressure is less than the fracture pressure, it is determined that the soluble temporary plugging balls are temporarily plugged unsuccessfully.

[0034] In a possible implementation manner, the processing unit is specifically configured to control the continuous increase of the pumping displacement of the completion fluid, and the first bottom-hole pressure changes with the change of the pumping displacement;

[0035] The determination unit is specifically configured to determine the first bottom-hole pressure corresponding to the inflection point as the fracture pressure of the first perforation interval when it is determined that the first bottom-hole pressure has an inflection point.

[0036] In a possible implementation, the determining unit is specifically configured to, when the soluble temporary plugging ball fails to plug, pump a plurality of soluble temporary plugging balls into the first perforation section again, and receive the third bottom-hole pressure of the target well reservoir sent by the pressure acquisition device until the third bottom-hole pressure is greater than or equal to the fracture pressure.

[0037] The processing unit is specifically configured to reduce the pumping displacement of the completion fluid to a preset displacement when it is determined that an inflection point appears in the first bottom-hole pressure.

[0038] In a possible implementation, the determining unit is specifically configured to obtain the in-situ stress of the target well reservoir; and determine the plurality of perforation sections and the perforation parameters of each perforation section according to the magnitudes of the principal stresses in the in-situ stress.

[0039] In a third aspect, an embodiment of the present application provides a reservoir stimulation device, which includes a memory and a processor; wherein,

[0040] The memory is used to store a computer program;

[0041] The processor is configured to read the computer program stored in the memory and execute a reservoir stimulation method described in any possible implementation of the first aspect above according to the computer program in the memory.

[0042] In a fourth aspect, an embodiment of the present application provides a computer-readable storage medium, in which computer-executable instructions are stored, and when the processor executes the computer-executable instructions, a reservoir stimulation method described in any possible implementation of the first aspect above is implemented.

[0043] In a fifth aspect, an embodiment of the present application provides a computer program product, including a computer program, which when executed by a processor, implements a reservoir stimulation method described in any possible implementation of the first aspect above.

[0044] It can be seen that for a reservoir stimulation method, device, and storage medium provided by an embodiment of the present application, when stimulating a target well reservoir, the plurality of perforation sections of the target well reservoir and the length and number of perforations of each perforation section are first determined; during the process of pumping the completion fluid and soluble temporary plugging balls into the perforation section according to the length and number of perforations of each perforation section, the first bottom-hole pressure and the second bottom-hole pressure of the target well reservoir are respectively collected by a pressure acquisition device; the temporary plugging state of the temporary plugging ball is determined according to the bottom-hole pressure collected by the pressure acquisition device; by collecting the bottom-hole pressure through the pressure acquisition device, the temporary plugging state of the temporary plugging ball can be accurately judged, and the efficiency of reservoir stimulation is improved. Description of the Drawings

[0045] Figure 1 Schematic flow chart of a reservoir stimulation method provided by an embodiment of the present application;

[0046] Figure 2 Schematic diagram of well logging data of a target well provided by an embodiment of the present application;

[0047] Figure 3 Graph showing the variation of bottom hole pressure and completion fluid injection rate with time provided by an embodiment of the present application;

[0048] Figure 4 Schematic structural diagram of a reservoir stimulation device provided by an embodiment of the present application;

[0049] Figure 5 Schematic structural diagram of another reservoir stimulation device provided by an embodiment of the present application.

[0050] Through the above-mentioned drawings, specific embodiments of the present disclosure have been shown, and there will be more detailed descriptions hereinafter. These drawings and textual descriptions are not intended to limit the scope of the concept of the present disclosure in any way, but to illustrate the concept of the present disclosure to those skilled in the art by referring to specific embodiments. Detailed Description of the Embodiment

[0051] Here, the exemplary embodiments will be described in detail, and the examples are shown in the drawings. When the following description refers to the drawings, unless otherwise indicated, the same numbers in different drawings represent the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with the present disclosure. On the contrary, they are merely examples of devices and methods consistent with some aspects of the present disclosure as detailed in the appended claims.

[0052] In the embodiments of the present application, "at least one" means one or more, and "a plurality" means two or more. "And / or" describes the association relationship of associated objects and indicates that three relationships may exist. For example, A and / or B may represent: A exists alone, A and B exist simultaneously, and B exists alone. Here, A and B may be singular or plural. In the textual description of the present application, the character " / " generally represents an "or" relationship between the associated objects before and after.

[0053] The technical solution provided by the embodiments of the present application can be applied to the scenario of oil and gas exploitation. In order to increase the production of a single well and the oil recovery rate, it is necessary to transform the reservoir. Among them, reservoir transformation is an important production-increasing method, which refers to using certain technological measures to transform the near-well zone or far-well area of the reservoir through physical and chemical methods, relieve the formation pollution in the near-well zone, or establish a high-conductivity flow channel in the formation, expand the seepage area of oil and gas into the wellbore, and communicate with the high-permeability oil and gas zones far from the wellbore, so as to achieve the purpose of increasing the production of a single well and the oil production rate.

[0054] At present, the commonly used transformation methods include the technology of staged fracturing with ball plugging. The technology of staged fracturing with ball plugging is to perforate the target reservoir to be fractured at one time, and use the differences in in-situ stress and reservoir physical properties between layers to temporarily plug the perforations by injecting temporary plugging balls, and complete the step-by-step transformation of each section. In theory, this technology can achieve staged fracturing of ultra-deep wells. The downhole string is simple, the requirements for the wellbore and the string are low, the construction is safe, time-saving, labor-saving and low-cost. However, it has high requirements for the distribution of the designed sections, the fracturing scale of the sections, and the accuracy of the timing of injecting temporary plugging balls.

[0055] At present, when using the technology of staged fracturing with ball plugging to transform the reservoir, for the sections with relatively low in-situ stress and good physical properties, the completion fluid is first pumped. During the process of pumping the completion fluid, the pumping displacement is continuously increased until the displacement of the completion fluid required for the perforated section obtained by theoretical calculation is reached. And according to the relationship between the bottom-hole pressure of the perforated section obtained by theoretical calculation and the pumped completion fluid, it is determined when to start injecting the ball and when to end injecting the temporary plugging ball; after ending the injection of the temporary plugging ball, the pumping displacement of the completion fluid is continuously increased until the displacement of the completion fluid required to fracture the second section is reached; then the injection of the temporary plugging ball for transformation is carried out step by step for each section repeatedly, so as to realize the transformation of the entire well reservoir. However, this method only carries out ball plugging transformation on the perforated section according to the theoretical calculation results to determine whether the soluble temporary plugging ball has completed the temporary plugging of the target section, resulting in the inability to fracture the second section when the displacement of the completion fluid is increased to the displacement required to fracture the second section before the soluble temporary plugging ball has completed the temporary plugging of the target section, and the efficiency of reservoir transformation is low.

[0056] In view of the above problems, the present application provides a reservoir transformation method. Since when using soluble temporary plugs to transform the reservoir of the target well, the bottom-hole pressure is increased by pumping the completion fluid and continuously increasing the displacement of the completion fluid to fracture the cracks in the perforated section, the bottom-hole pressure of the reservoir of the target well during the entire transformation process can be monitored by a pressure acquisition device in real time. Among them, according to the first bottom-hole pressure sent by the pressure acquisition device, it can be accurately determined whether the target perforated section has been fractured, and according to the second bottom-hole pressure sent by the pressure acquisition device, the temporary plugging state of the soluble temporary plugging ball can be accurately determined.

[0057] Based on the above technical concept, an embodiment of the present application provides a reservoir stimulation method, which uses a pressure acquisition device to collect and transmit the bottom-hole pressure of the reservoir of the target well in real time, controls the displacement of the completion fluid and the soluble temporary plugging balls pumped into the perforation section according to the magnitude of the bottom-hole pressure, and determines the temporary plugging state of the perforation section, thereby completing the stimulation of the reservoir of the target well and improving the accuracy and efficiency of reservoir stimulation.

[0058] Next, the reservoir stimulation method provided by the present application will be described in detail through specific embodiments. It can be understood that these specific embodiments can be combined with each other, and the same or similar concepts or processes may not be repeated in some embodiments.

[0059] Figure 1 The following is a schematic flowchart of a reservoir stimulation method provided by an embodiment of the present application. This reservoir stimulation method can be executed by software and / or hardware devices. For example, the hardware device can be a reservoir stimulation device, and this reservoir stimulation device can be integrated in a terminal device. For example, please refer to Figure 1 As shown, this reservoir stimulation method may include:

[0060] S101. Determine multiple perforation sections of the reservoir of the target well and the perforation parameters of each perforation section.

[0061] Regarding the differences in various parts of the reservoir of the target well, when stimulating the reservoir of the target well, it is necessary to first design the perforation sections according to the difference values in various parts of the reservoir of the target well, so as to determine multiple perforation sections and the perforation parameters of each perforation section. Among them, the perforation parameters include the length of the perforation section and the number of perforations.

[0062] Furthermore, when determining multiple perforation sections of the reservoir of the target well and the perforation parameters of each perforation section, the in-situ stress of the reservoir of the target well can be obtained, and multiple perforation sections and the perforation parameters of each perforation section can be determined according to the magnitude of the principal stress in the in-situ stress.

[0063] Specifically, when determining the distribution of multiple perforation intervals, for the convenience of construction, it is necessary to divide the multiple perforation intervals in a stepped manner according to the physical properties of the reservoir of the target well and the magnitude of the in-situ stress, ensuring that there is a fixed pressure difference between every two adjacent perforation intervals, or there are stepped differences in the physical properties between the perforation intervals. For example, the stress difference can be any value between 2 - 3 MPa. Among them, the physical properties of the reservoir of the target well are part of the logging parameters measured by a logging tool during the exploitation of the target well, and no specific limitations are imposed on the specific logging tool in the embodiments of the present application. For the determination of the in-situ stress, taking the imaging logging technology as an example, the collapse depth and width of the wellbore collapse section can be obtained through the dual caliper curve and the borehole wall imaging logging image, and an in-situ stress model is established. According to the logging image measured by the imaging logging technology, the fracture balance point of the wellbore stress is determined, and an in-situ stress calculation model is established to determine the magnitude of the in-situ stress and the principal stress. In addition, the imaging logging technology can accurately determine the wellbore collapse azimuth and the fracture strike, thereby determining the direction of the in-situ stress. The embodiments of the present application only take the imaging logging technology as an example for illustration, but it does not mean that the embodiments of the present application are only limited to this.

[0064] Exemplarily, when determining multiple perforation intervals and the perforation parameters of each perforation interval according to the magnitude of the principal stress in the in-situ stress, in order to avoid fractures occurring simultaneously in each perforation interval, it is necessary to determine the distribution of the perforation intervals in combination with the physical properties of the target reservoir. Assuming that the distribution of the perforation intervals is stepped, when the target well is a vertical well, if the physical properties and the principal stress of each section of the reservoir of the target well are basically the same, then the positions of some perforation intervals are determined as the positions in the upper or lower part of the reservoir of the target well, and the differences of each perforation interval are set according to the physical properties and the principal stress of each section, and the reservoir of the target well is determined as multiple perforation intervals; if there are obvious differences in the physical properties and the principal stress of each section of the reservoir of the target well, then multiple perforation intervals of the reservoir of the target well are determined according to the differences. When the target well is a horizontal well, since it has only one reservoir and the differences in the physical properties and the principal stress of its reservoir are not obvious, at least three physical properties among many physical properties and the sections with close principal stress need to be determined as the perforation interval step units, and the entire reservoir is determined as multiple perforation intervals according to the perforation interval step units. In addition, for the convenience of construction, the perforation interval with the best physical properties or the minimum in-situ stress is determined as the first perforation interval, and the perforation interval with slightly worse physical properties or in-situ stress is used as the second perforation interval, and so on, and the perforation intervals with a stepped distribution are numbered in sequence. The embodiments of the present application only take the above method for determining the perforation intervals as an example for illustration, but it does not mean that the embodiments of the present application are only limited to this.

[0065] In this method, the distribution of multiple perforation intervals is determined based on the magnitudes of the principal stresses in the in-situ stress of the target well reservoir, fully considering the issues of in-situ stress on the fracture extension direction and propagation, sand production in the reservoir during the exploitation process, and formation slippage and creep caused by water injection, thereby improving the efficiency of fracturing the reservoir of each perforation interval.

[0066] When determining the distribution of the perforation intervals, the length information of each perforation interval is obtained; the number of perforations for each perforation interval can be determined based on the length of the perforation interval, the hole diameter, and the perforation density. The specific relationship is that the length of the perforation divided by the hole diameter divided by the perforation density equals the number of perforations for that perforation interval. In the embodiments of the present application, no specific limitation is imposed on the hole diameter.

[0067] S102. According to the perforation parameters of the first perforation interval among the multiple perforation intervals, completion fluid is pumped into the first perforation interval, and the first bottom-hole pressure of the target well reservoir sent by the pressure acquisition device in the target well reservoir is received.

[0068] Before pumping the completion fluid into the first perforation interval according to the perforation parameters of the first perforation interval among the multiple perforation intervals, the position of the pressure acquisition device in the target well reservoir needs to be determined. Assuming that the pressure acquisition device is a fiber optic direct reading pressure gauge, in order to ensure that it can accurately collect the bottom-hole pressure and reduce the distortion of the bottom-hole pressure caused by the liquid column pressure, its placement position can be at the end of the target well reservoir string, that is, at a position 20 - 30 m above the top of the target well reservoir. The embodiments of the present application are only described by taking the fiber optic direct reading pressure gauge as an example, and do not mean that the embodiments of the present application are limited thereto.

[0069] According to the perforation parameters of the first perforation interval, completion fluid is pumped into the first perforation interval, and it is necessary to control the continuous increase of the pumping displacement of the completion fluid. At this time, the first bottom-hole pressure changes with the change of the pumping displacement of the completion fluid, that is, the first bottom-hole pressure continuously increases. When an inflection point appears in the first bottom-hole pressure, the first bottom-hole pressure corresponding to the inflection point is determined as the fracture pressure of the first perforation interval, which means that a fracture appears in the first perforation interval. At this time, when an inflection point appears in the first bottom-hole pressure, in order to determine that this point is indeed an inflection point, the pumping displacement of the completion fluid can be continuously increased until an obvious inflection point appears. The embodiments of the present application do not make specific limitations on this.

[0070] Specifically, during the process of pumping the completion fluid into the first perforation interval and continuously increasing the displacement of the completion fluid, the displacement of the completion fluid can be increased at a speed of 0.3 - 0.5 m 3 / min. At this time, if the first bottom-hole pressure detected by the fiber optic direct reading pressure gauge increases slowly, the speed of increasing the displacement of the completion fluid can be increased to 0.5 - 1 m 3 / min. Thus, the time for the bottom-hole pressure of the first stage to reach the fracture pressure is shortened. In the embodiments of the present application, only the example of increasing the speed is used for illustration, but it does not mean that the embodiments of the present application are limited thereto. In addition, the completion fluid can be a low-viscosity fracturing fluid or skating water. The selection of the completion fluid can be based on the parameters of the reservoir of the actual target well. The embodiments of the present application do not impose any restrictions on this.

[0071] In this method, since the bottom-hole pressure increases with the increase of the pumping rate of the completion fluid until the fracture in the first perforation interval is broken, the bottom-hole pressure decreases. At this time, the first bottom-hole pressure sent by the pressure acquisition device is determined as the fracture pressure of the first perforation interval. Through the pressure acquisition device, the fracture pressure value of the first perforation interval can be accurately obtained, avoiding the error of determining the fracture pressure of the first perforation interval by theoretical calculation.

[0072] Further, when it is determined that the inflection point of the first bottom-hole pressure appears, the pumping rate of the completion fluid is reduced to a preset rate.

[0073] Exemplarily, when it is determined that the inflection point of the first bottom-hole pressure appears, the pumping rate of the completion fluid can be kept unchanged first, and after a period of time, the pumping rate of the completion fluid is reduced to the preset rate, so that the bottom-hole pressure remains stable for a period of time, preparing for pumping soluble temporary plugging balls into the first perforation interval. Specifically, the time for keeping the pumping rate of the completion fluid unchanged can be set according to the actual reservoir stimulation of the target well. The embodiments of the present application do not impose any restrictions on whether to keep the pumping rate of the completion fluid unchanged for a period of time.

[0074] Specifically, the bottom-hole pressure sent by the fiber optic direct reading pressure gauge gradually decreases with the reduction of the pumping rate. At this time, the bottom-hole pressure of the target well reservoir can continue to be detected by the fiber optic direct reading pressure gauge. In this process, the pumping rate of the completion fluid can be reduced at a fixed speed. The embodiments of the present application do not impose any restrictions on the specific speed. Receive the fourth bottom-hole pressure sent by the fiber optic direct reading pressure gauge at the bottom of the well when the completion fluid is reduced to the preset rate, and determine the shut-in pressure of the first perforation interval according to the fourth bottom-hole pressure. According to the reduction speed of the pumping rate of the completion fluid and the fourth bottom-hole pressure of the target well reservoir detected by the fiber optic direct reading pressure gauge, the bottom-hole pressure of the target well reservoir when the pumping rate of the completion fluid is reduced to 0 can be deduced, that is, the shut-in pressure of the first perforation interval.

[0075] In this method, when it is determined that the inflection point of the first bottom-hole pressure appears, reducing the pumping rate of the completion fluid to the preset rate can save the completion fluid and avoid drastic changes in the bottom-hole pressure caused by too large a pumping rate of the completion fluid, thus affecting the pumping of soluble temporary plugging balls.

[0076] S103. Control the pumping of a plurality of soluble temporary plugging balls into the first perforation interval, and receive the second bottom-hole pressure of the target well reservoir sent by the pressure acquisition device.

[0077] Multiple soluble temporary plugging balls need to be pumped into the first perforation interval together with the completion fluid. During the process of pumping the soluble temporary plugging balls into the first perforation interval, the fiber optic direct reading pressure gauge needs to collect the second bottom hole pressure of the target well reservoir in real time.

[0078] Specifically, the number of soluble temporary plugging balls can be determined according to the perforation parameters of the first perforation interval. Specifically: determine the diameter of the temporary plugging ball according to the hole diameter of the perforations in the first perforation interval; determine the number of soluble temporary plugging balls according to the number of perforations. In order to achieve the temporary plugging effect of the soluble temporary plugging balls and ensure that all the perforations in the perforation interval can be temporarily plugged, the diameter of the soluble temporary plugging ball needs to be greater than the hole diameter, and the number of soluble temporary plugging balls needs to be greater than the number of perforations in the first perforation interval. Assuming that the diameter of the soluble temporary plugging ball is 1.2 times the hole diameter and its number is 1.2 times the number of perforations, the embodiments of the present application only take 1.2 times as an example to set the diameter and number of the soluble temporary plugging balls, but it does not mean that the present application is only limited to this.

[0079] Exemplarily, when the pumping displacement of the completion fluid is reduced to the preset displacement, start pumping the soluble temporary plugging balls into the first perforation interval. When pumping the soluble temporary plugging balls, 1.2 times the number of perforations of soluble temporary plugging balls can be added to the completion fluid, so that they enter the first perforation interval along with the completion fluid. Under the action of the self-gravity, pressure gradient force and resistance of the soluble temporary plugging balls, the temporary plugging balls realize the temporary plugging of the perforation holes. At this time, continue to receive the second bottom hole pressure of the target well reservoir sent by the fiber optic direct reading pressure gauge. In order to crack the second perforation interval while temporarily plugging the first perforation interval, the pumping displacement of the completion fluid can be continuously increased while adding the soluble temporary plugging balls.

[0080] In this method, the perforations in the first perforation interval are temporarily plugged by pumping multiple soluble temporary plugging balls into the first perforation interval. By receiving the second bottom hole pressure sent by the pressure acquisition device, the change of the bottom hole pressure can be monitored in real time.

[0081] S104. Determine the temporary plugging state of the soluble temporary plugging balls according to the first bottom hole pressure and the second bottom hole pressure, so as to transform the reservoir.

[0082] After the soluble temporary plugging ball enters the first perforation section, as the soluble temporary plugging ball plugs the perforations in the first perforation section one by one, the bottom hole pressure will gradually increase, that is, the second bottom hole pressure transmitted by the fiber optic direct reading pressure gauge gradually increases. By judging whether the second bottom hole pressure is greater than the fracture pressure, the temporary plugging state of the soluble temporary plugging ball is determined; it includes: if the second bottom hole pressure is greater than or equal to the fracture pressure of the first perforation section, it is determined that the soluble temporary plugging ball has successfully plugged, that is, the soluble temporary plugging ball plugs all the perforations in the first perforation section; if the second bottom hole pressure is less than the fracture pressure of the first perforation section, it is determined that the soluble temporary plugging ball has failed to plug, that is, the soluble temporary plugging ball has not plugged all the perforations in the first perforation section.

[0083] In this method, by judging the temporary plugging state of the soluble temporary plugging ball for the first perforation section based on the bottom hole pressure of the target well reservoir collected by the received fiber optic direct reading pressure gauge, the temporary plugging state can be judged more accurately, thus avoiding the problem of misjudgment caused by blindly judging the temporary plugging ball of the soluble temporary plugging ball.

[0084] Further, if the soluble temporary plugging ball fails to plug, the soluble temporary plugging ball is pumped into the first perforation section again. At this time, the number of soluble temporary plugging balls pumped in with the completion fluid is less than the number of soluble temporary plugging balls added for the first time, which can be 30%-70% of the number of temporary plugging balls added for the first time. Specifically, it can be determined according to the difference between the second bottom hole pressure and the fracture pressure of the first perforation section. The number of soluble temporary plugging balls pumped in again is proportional to the difference value, that is, the larger the difference value, the more soluble temporary plugging balls are added. The embodiments of the present application do not specifically limit the number of soluble temporary plugging balls added for the second time. While adding the soluble temporary plugging ball for the second time, the third bottom hole pressure of the target well reservoir transmitted by the fiber optic direct reading pressure gauge is received. During the process of adding the soluble temporary plugging ball, the third bottom hole pressure gradually increases until the third bottom hole pressure is greater than or equal to the fracture pressure of the first perforation section, then it is determined that the soluble temporary plugging ball has successfully plugged, that is, the soluble temporary plugging ball plugs all the perforations in the first perforation section. Exemplarily, to avoid waste of soluble temporary plugging balls, when adding the soluble temporary plugging ball for the second time, a small amount of temporary plugging balls can be added first, and the temporary plugging state can be determined according to the third bottom hole pressure transmitted by the fiber optic direct reading pressure gauge, so as to judge whether to continue adding soluble temporary plugging balls. In this regard, the embodiments of the present application do not make any restrictions.

[0085] In this method, by the magnitude of the third bottom hole pressure of the target well reservoir transmitted by the pressure acquisition device, the temporary plugging state of the first perforation section after adding the temporary plugging ball for the second time is determined, making the process of adding the soluble temporary plugging ball for the second time more accurate.

[0086] Exemplarily, after determining the successful temporary plugging of the soluble temporary plugging ball, the completion fluid can be continuously pumped into the reservoir of the target well. The bottom hole pressure increases continuously with the pumping of the completion fluid until the bottom hole pressure shows an inflection point again. The bottom hole pressure at the second inflection point is determined as the fracture pressure of the second perforation interval. When the bottom hole pressure shows an inflection point for the second time, it indicates that the fractures in the second perforation interval are opened. Determine the number of perforations in the second perforation interval and the number of soluble temporary plugging balls put in according to the above steps, and temporarily plug the second perforation interval with soluble temporary plugging balls through a fiber optic direct reading pressure gauge. The specific method can refer to the above steps, which will not be elaborated in the embodiments of the present application. It can be understood that after determining the successful temporary plugging of the second perforation interval by the soluble temporary plugging ball, the remaining perforation intervals can be temporarily plugged one by one according to the above steps, so as to complete the transformation of the entire reservoir of the target well.

[0087] Exemplarily, after completing the transformation of multiple perforation intervals, according to the magnitudes of the fracture pressure and the shut-in pressure of each perforation interval, the gradient difference of the artificial fracture extension pressure of each perforation interval can be calculated, and the result is compared with the theoretical calculated value obtained through logging parameters to further determine that the transformation of the entire reservoir of the target well is completed.

[0088] It can be seen that the reservoir transformation method provided by the embodiments of the present application controls the displacement of the completion fluid pumped into the reservoir of the target well and the temporary plugging state after pumping in multiple soluble temporary plugging balls through the bottom hole pressure transmitted in real time by the received pressure acquisition device when transforming the reservoir of the target well, so as to complete the temporary plugging of all perforation intervals, improving the accuracy and efficiency of reservoir transformation.

[0089] To facilitate the understanding of the technical method provided by the present application, the following describes in detail a reservoir transformation method provided by the present application through specific embodiments. In this embodiment, the DB12 well in the Kelasu structural belt in front of the Kuqa Mountains is taken as an example, that is, the target well is the DB12 well in the Kelasu structural belt in front of the Kuqa Mountains. The logging data of this well is detected by a logging tool. Specifically, it can be referred to Figure 2 as shown Figure 2 which is a schematic diagram of the logging data of a target well provided by the embodiments of the present application. As Figure 2 shown, the reservoir of this well is the Bashijiqike Formation of the Cretaceous, the completion depth is 5730 m, the longitudinal span of its oil-bearing layer exceeds 115 m, and according to Figure 2The completion data shown indicate that the bottom-hole pressure of this well exceeds 115 MPa and the bottom-hole temperature is approximately 180 °C. According to the logging data, the minimum horizontal principal stress of the reservoir of this well is between 100 MPa and 110 MPa. Considering the physical characteristics of this well, it is determined that there are two perforation intervals in this target well. The first perforation interval is between 5427 - 5460 m, and the second perforation interval is between 5490 - 5520 m. That is, the lengths of the first perforation interval and the second perforation interval are 33 m and 30 m respectively. The average minimum horizontal principal stresses of the perforation intervals are 103 MPa and 107 MPa respectively. That is, the difference in the minimum horizontal principal stresses between the two perforation intervals is between 3 - 5 MPa.

[0090] Assume that the perforation density of both the first perforation interval and the second perforation interval is 10 holes per meter, and the hole diameter is 10 mm. Then it is determined that the number of perforations in the first perforation interval is 330 holes, and the number of perforations in the second perforation interval is 300. Set the diameter and quantity of the soluble temporary plugging balls to be 1.2 times the hole diameter and the number of perforations respectively. That is, the diameter of the soluble temporary plugging balls is 12 mm. The number of soluble temporary plugging balls required for the first perforation interval is 396, and the number of soluble temporary plugging balls required for the second perforation interval is 360. According to the position of the first perforation interval, the placement position of the fiber optic direct-reading bottom-hole pressure gauge is at 5400 m below the well.

[0091] When reconstructing the first perforation interval, the variation of the bottom-hole pressure and the displacement of the completion fluid injected by the pump with time can be seen in Figure 3 shown Figure 3 which is a curve graph of the variation of the bottom-hole pressure and the displacement of the completion fluid injected by the pump with time provided by an embodiment of this application. According to Figure 3 it can be seen that during the process of increasing the displacement of the completion fluid injected by the pump, the bottom-hole pressure gradually increases. When the displacement of the completion fluid injected by the pump increases to 3.8 m 3 / min, the bottom-hole pressure starts to show an inflection point A. At this time, when continuing to increase the displacement of the completion fluid injected by the pump, when the displacement of the completion fluid injected by the pump reaches 4.8 m 3 / min, the bottom-hole pressure shows an obvious inflection point. At this time, the bottom-hole pressure corresponding to the inflection point A is determined as the fracture pressure of the first perforation interval. That is, the fracture pressure of the first perforation interval is 118 MPa. It can be seen that after the first perforation interval shows the fracture pressure, its bottom-hole pressure instantaneously drops to 107 MPa. When the bottom-hole pressure reaches the fracture pressure of the first perforation interval, the displacement of the completion fluid injected by the pump remains unchanged until the bottom-hole pressure reaches point B. That is, after the bottom-hole pressure maintains a stable change for a period of time, it continues to decrease. It is determined that the injection of the completion fluid meets the construction requirements of the first perforation interval. At this time, the displacement of the completion fluid injected by the pump starts to be reduced until the displacement of the completion fluid injected by the pump is reduced to 1.8 m 3 / min, and the corresponding bottom-hole pressure is 95 MPa. Therefore, it can be deduced that when the pumping rate of the completion fluid drops to 0, the bottom-hole pressure is 92 MPa, that is, the shut-off pressure of the first perforation section is 92 MPa.

[0092] Further, maintain the pumping rate of the completion fluid at 1.8 m 3 / min, and start pumping soluble temporary plugging balls. The number of soluble temporary plugging balls added is 396. During the process of adding the temporary plugging balls, the bottom-hole pressure gradually decreases. Until reaching point C, the bottom-hole pressure starts to increase, indicating that the temporary plugging balls enter the first perforation section and start to temporarily plug the holes in the first perforation section. At point D, the bottom-hole pressure changes slowly, and the bottom-hole pressure at point D does not reach the fracture pressure of the first perforation section. Then it is determined that the soluble temporary plugging balls invested do not completely plug all the holes in the first perforation section. At this time, pump soluble temporary plugging balls into the first perforation section again, and the total amount of the temporarily plugged balls invested again is 50% of the first investment; after adding the temporary plugging balls again, the bottom-hole pressure gradually increases and exceeds the fracture pressure of the first perforation section. It can be determined that the soluble temporary plugging balls complete the temporary plugging of all the holes in the first perforation section, that is, the transformation of the first perforation section is completed.

[0093] After completing the transformation of the first perforation section, continue to increase the pumping rate of the completion fluid. The bottom-hole pressure increases with the increase of the pumping rate of the completion fluid. There is an obvious inflection point at point E for the bottom-hole pressure. Determine the bottom-hole pressure corresponding to point E as the fracture pressure of the second perforation section, that is, the fracture pressure of the second perforation section is 112 MPa. Repeat the above process of transforming the first perforation section to transform the second perforation section. For the change of the bottom-hole pressure and the change of the displacement during the transformation of the second perforation section, see Figure 3 as shown, and this embodiment will not elaborate here. From Figure 3 it can be seen that the shut-off pressure of the second perforation section is 96 MPa. After completing the transformation of the second perforation section, gradually reduce the pumping rate of the completion fluid to 0.

[0094] From the above description, it can be obtained that the difference between the fracture pressure of the second perforation section and the fracture of the first perforation section is 5 MPa, and the difference between the shut-off pressure of the second perforation section and the shut-off pressure of the first perforation section is 4 MPa. The differences between the fracture pressures and shut-off pressures of the two perforation sections are both close to the difference in the minimum horizontal principal stresses of the two perforation sections obtained from the completion data within 3 - 5 MPa, that is, it shows that the two perforation sections are successfully transformed by this method.

[0095] By applying the reservoir stimulation method provided in the embodiment of the present application, the layered stimulation of Well DB12 in the Dabei Block of the Tarim Oilfield is completed. Before using the reservoir stimulation method provided in the embodiment of the present application for stimulation, the oil pressure of this well is between 31.433 - 49.450 MPa, and the daily gas production is about 79536 m 3, no liquid is produced. After the reservoir is transformed using the reservoir transformation method provided in the embodiments of the present application, the oil pressure of this well becomes between 64.021 - 74.768 MPa, and the daily gas production can be between 305672 - 329867 m 3 between, and the daily oil production can be between 2.16 - 6.00 m 3 between, that is, the pressure increases by 100% and the gas production increases by 300% after the transformation. This technical solution makes the entire reservoir transformation process more accurate through the fiber optic direct reading pressure gauge, thereby increasing the production of Well DB12 in the Dabei Block of the Tarim Oilfield.

[0096] In summary, a reservoir transformation method provided by the embodiments of the present application adjusts the pumping displacement of the completion fluid according to the bottom hole pressure data sent in real time by the fiber optic direct reading pressure gauge, and determines the temporary plugging state of the soluble temporary plugging balls for the perforated section; in addition, it can be determined whether the first perforated section is completed and the second perforated section is fractured through the fiber optic direct reading pressure gauge, improving the accuracy of the temporary plugging of the perforation holes in the perforated section by the soluble temporary plugging balls and the efficiency of reservoir transformation.

[0097] Figure 4 It is a schematic structural diagram of a reservoir transformation device 40 provided by the embodiments of the present application. For example, please refer to Figure 4 shown, the reservoir transformation device 40 may include:

[0098] A determination unit 401, configured to determine multiple perforated sections of the target well reservoir and the perforation parameters of each perforated section, where the perforation parameters include the length of the perforated section and the number of perforations;

[0099] A processing unit 402, configured to pump the completion fluid into the first perforated section according to the perforation parameters of the first perforated section among the multiple perforated sections;

[0100] A receiving unit 403, configured to receive the first bottom hole pressure of the target well reservoir sent by the pressure acquisition device in the target well reservoir;

[0101] The processing unit 402 is further configured to control the pumping of multiple soluble temporary plugging balls into the first perforated section;

[0102] The receiving unit 403 is further configured to receive the second bottom hole pressure of the target well reservoir sent by the pressure acquisition device;

[0103] The determination unit 401 is further configured to determine the temporary plugging state of the soluble temporary plugging balls according to the first bottom hole pressure and the second bottom hole pressure, so as to transform the reservoir.

[0104] In a possible implementation, the determination unit 401 is specifically configured to determine the fracture pressure of the first perforation section according to the first bottom-hole pressure, and determine whether the second bottom-hole pressure is greater than the fracture pressure. If the second bottom-hole pressure is greater than or equal to the fracture pressure, it is determined that the soluble temporary plugging ball has successfully plugged. If the second bottom-hole pressure is less than the fracture pressure, it is determined that the soluble temporary plugging ball has failed to plug.

[0105] In a possible implementation, the processing unit 402 is specifically configured to control the pump injection rate of the completion fluid to continuously increase, and the first bottom-hole pressure changes with the change of the pump injection rate.

[0106] The determination unit 401 is specifically configured to, when it is determined that an inflection point appears in the first bottom-hole pressure, determine the first bottom-hole pressure corresponding to the inflection point as the fracture pressure of the first perforation section.

[0107] In a possible implementation, the determination unit 401 is specifically configured to, when the soluble temporary plugging ball fails to plug, pump multiple soluble temporary plugging balls into the first perforation section again, and receive the third bottom-hole pressure of the target well reservoir sent by the pressure acquisition device until the third bottom-hole pressure is greater than or equal to the fracture pressure.

[0108] The processing unit 402 is specifically configured to, when it is determined that an inflection point appears in the first bottom-hole pressure, reduce the pump injection rate of the completion fluid to a preset rate.

[0109] In a possible implementation, the determination unit 401 is specifically configured to obtain the in-situ stress of the target well reservoir, and determine multiple perforation sections and the perforation parameters of each perforation section according to the magnitude of the principal stress in the in-situ stress.

[0110] The reservoir stimulation device 40 provided by the embodiments of the present application can execute the technical solutions of the reservoir stimulation method in any of the above embodiments. Its implementation principle and beneficial effects are similar to those of the reservoir stimulation method. For details, please refer to the implementation principle and beneficial effects of the reservoir stimulation method, which will not be elaborated here.

[0111] Figure 5 FIG. is a schematic structural diagram of another reservoir stimulation device 50 provided by the embodiments of the present application. For example, please refer to Figure 5 As shown, the reservoir stimulation device 50 may include a processor 501 and a memory 502;

[0112] Among them,

[0113] The memory 502 is used to store computer programs.

[0114] The processor 501 is configured to read the computer program stored in the memory 502 and execute the technical solutions of the reservoir stimulation method in any of the above embodiments according to the computer program in the memory 502.

[0115] Optionally, the memory 502 can be either independent or integrated with the processor 501. When the memory 502 is a device independent of the processor 501, the reservoir stimulation device 50 may further include: a bus for connecting the memory 502 and the processor 501.

[0116] Optionally, this embodiment further includes: a communication interface, which can be connected to the processor 501 through a bus. The processor 501 can control the communication interface to implement the receiving and sending functions of the above-mentioned reservoir stimulation device 50.

[0117] The reservoir stimulation device 50 shown in the embodiments of the present invention can execute the technical solutions of the reservoir stimulation method in any of the above embodiments. Its implementation principle and beneficial effects are similar to those of the reservoir stimulation method. For details, please refer to the implementation principle and beneficial effects of the reservoir stimulation method, which will not be elaborated here.

[0118] The embodiments of the present invention also provide a computer-readable storage medium, in which computer-executable instructions are stored. When the processor executes the computer-executable instructions, the technical solutions of the reservoir stimulation method in any of the above embodiments are implemented. Its implementation principle and beneficial effects are similar to those of the reservoir stimulation method. For details, please refer to the implementation principle and beneficial effects of the reservoir stimulation method, which will not be elaborated here.

[0119] In several embodiments provided by the present invention, it should be understood that the disclosed devices and methods can be implemented in other ways. For example, the device embodiments described above are merely illustrative. For example, the division of the units is only a logical function division. In actual implementation, there may be other division methods. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the displayed or discussed couplings or direct couplings or communication connections to each other can be through some interfaces. The indirect couplings or communication connections of the devices or units can be in electrical, mechanical or other forms.

[0120] The unit described as a separation component may or may not be physically separated. The component presented as a unit may or may not be a physical unit, that is, it may be located in one place or distributed across multiple network units. Some or all of the units can be selected according to actual needs to achieve the purpose of the solution of this embodiment. Additionally, in each embodiment of the present invention, the functional units can be integrated in a processing unit, or each unit can physically exist alone, or two or more units can be integrated in one unit. The above integrated unit can be implemented in the form of hardware or in the form of a combination of hardware and software functional units.

[0121] The above integrated module implemented in the form of a software functional module can be stored in a computer-readable storage medium. The above software functional module stored in a storage medium includes several instructions for causing a computer device (which can be a personal computer, a server, or a network device, etc.) or a processor (English: processor) to execute some steps of the methods in each embodiment of the present invention.

[0122] It should be understood that the above processor can be a central processing unit (English: Central Processing Unit, abbreviated as: CPU), or it can also be other general-purpose processors, digital signal processors (English: Digital Signal Processor, abbreviated as: DSP), application specific integrated circuits (English: Application Specific Integrated Circuit, abbreviated as: ASIC), etc. The general-purpose processor can be a microprocessor or the processor can also be any conventional processor, etc. The steps of the method disclosed in combination with the invention can be directly implemented by a hardware processor or implemented by a combination of hardware and software modules in the processor.

[0123] The memory may include high-speed RAM memory and may also include non-volatile storage NVM, such as at least one disk memory, and can also be a USB flash drive, a mobile hard disk, a read-only memory, a disk, or an optical disc, etc.

[0124] The bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. The bus can be divided into an address bus, a data bus, a control bus, etc. For the sake of representation, the bus in the drawings of the present invention is not limited to only one bus or one type of bus.

[0125] The above computer-readable storage medium may be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic memory, flash memory, a magnetic disk or an optical disk. The storage medium may be any available medium accessible by a general-purpose or special-purpose computer.

[0126] Finally, it should be noted that: the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit them; although the present application has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that: they can still modify the technical solutions recorded in the foregoing embodiments, or perform equivalent replacements on some or all of the technical features; and these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present application.

Claims

1. A reservoir stimulation method, characterized in that, it includes: Determine multiple perforation intervals of the target well reservoir and the perforation parameters of each perforation interval, where the perforation parameters include the length of the perforation interval and the number of perforations; According to the perforation parameters of the first perforation interval among the multiple perforation intervals, pump completion fluid into the first perforation interval, and receive the first bottom-hole pressure of the target well reservoir sent by the pressure acquisition device in the target well reservoir; Control the pumping of multiple soluble temporary plugging balls into the first perforation interval, and receive the second bottom-hole pressure of the target well reservoir sent by the pressure acquisition device; Determine the temporary plugging state of the soluble temporary plugging balls according to the first bottom-hole pressure and the second bottom-hole pressure, so as to stimulate the reservoir; The determining the temporary plugging state of the soluble temporary plugging balls according to the first bottom-hole pressure and the second bottom-hole pressure includes: Determine the fracture pressure of the first perforation interval according to the first bottom-hole pressure; Judge whether the second bottom-hole pressure is greater than the fracture pressure; If the second bottom-hole pressure is greater than or equal to the fracture pressure, it is determined that the soluble temporary plugging ball is successfully temporarily plugged; If the second bottom-hole pressure is less than the fracture pressure, it is determined that the soluble temporary plugging ball is temporarily plugged unsuccessfully; The determining the fracture pressure of the first perforation interval according to the first bottom-hole pressure includes: Control the continuous increase of the pumping displacement of the completion fluid, and the first bottom-hole pressure changes with the change of the pumping displacement; When it is determined that the first bottom-hole pressure has an inflection point, determine the first bottom-hole pressure corresponding to the inflection point as the fracture pressure of the first perforation interval; The determining multiple perforation intervals of the target well reservoir and the perforation parameters of each perforation interval includes: Obtain the in-situ stress of the target well reservoir, and perform stepped division on multiple perforation intervals according to the physical properties of the target well reservoir and the magnitude of the in-situ stress, so as to ensure that there is a fixed pressure difference between every two adjacent perforation intervals, or there are stepped differences in the physical properties between each perforation interval; Determine the distribution of the perforation intervals according to the magnitude of the principal stress in the in-situ stress, and combine with the physical properties of the target reservoir to determine the multiple perforation intervals and the perforation parameters of each perforation interval.

2. The method according to claim 1, characterized in that, the method further includes: If the soluble temporary plugging ball is temporarily plugged unsuccessfully, pump multiple soluble temporary plugging balls into the first perforation interval again, and receive the third bottom-hole pressure of the target well reservoir sent by the pressure acquisition device until the third bottom-hole pressure is greater than or equal to the fracture pressure.

3. The method according to claim 1, characterized in that, the method further includes: When it is determined that the first bottom-hole pressure has an inflection point, reduce the pumping displacement of the completion fluid to a preset displacement.

4. A reservoir stimulation device, characterized in that, it includes: A determination unit for determining multiple perforation intervals of the target well reservoir and the perforation parameters of each perforation interval, where the perforation parameters include the length of the perforation interval and the number of perforations; A processing unit for pumping completion fluid into the first perforation interval according to the perforation parameters of the first perforation interval among the multiple perforation intervals; A receiving unit, configured to receive the first bottom-hole pressure of the target well reservoir sent by a pressure acquisition device in the target well reservoir; The processing unit is further configured to control the pumping of a plurality of soluble temporary plugging balls into the first perforation section; The receiving unit is further configured to receive the second bottom-hole pressure of the target well reservoir sent by the pressure acquisition device; The determining unit is further configured to determine the temporary plugging state of the soluble temporary plugging ball according to the first bottom-hole pressure and the second bottom-hole pressure, so as to transform the reservoir; For determining the temporary plugging state of the soluble temporary plugging ball according to the first bottom-hole pressure and the second bottom-hole pressure, the determining unit specifically is configured to: Determine the fracture pressure of the first perforation section according to the first bottom-hole pressure; Judge whether the second bottom-hole pressure is greater than the fracture pressure; If the second bottom-hole pressure is greater than or equal to the fracture pressure, it is determined that the soluble temporary plugging ball is successfully temporarily plugged; If the second bottom-hole pressure is less than the fracture pressure, it is determined that the soluble temporary plugging ball fails to be temporarily plugged; For determining the fracture pressure of the first perforation section according to the first bottom-hole pressure, the determining unit specifically is configured to: Control the pumping displacement of the completion fluid to increase continuously, and the first bottom-hole pressure changes with the change of the pumping displacement; When it is determined that an inflection point appears in the first bottom-hole pressure, determine the first bottom-hole pressure corresponding to the inflection point as the fracture pressure of the first perforation section; For determining a plurality of perforation sections of the target well reservoir and the perforation parameters of each perforation section, the determining unit specifically is configured to: Obtain the in-situ stress of the target well reservoir, and perform stepped division on a plurality of perforation sections according to the physical properties of the target well reservoir and the magnitude of the in-situ stress, so as to ensure that there is a fixed pressure difference between every two adjacent perforation sections, or there are stepped differences in the physical properties between each perforation section; Determine the distribution of the perforation sections according to the magnitude of the principal stress in the in-situ stress, and in combination with the physical properties of the target reservoir, and determine the plurality of perforation sections and the perforation parameters of each perforation section.

5. A reservoir transformation device Characterized in that It includes a memory and a processor; wherein, The memory is used for storing a computer program; The processor is configured to read the computer program stored in the memory, and execute a reservoir transformation method according to any one of claims 1-3 above based on the computer program in the memory.

6. A computer-readable storage medium Characterized in that The computer-readable storage medium stores computer-executable instructions, and when the processor executes the computer-executable instructions, a reservoir transformation method according to any one of claims 1-3 above is implemented.

7. A computer program product, including a computer program Characterized in that When the computer program is executed by the processor, a reservoir transformation method according to any one of claims 1-3 above is implemented.

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