CN113326995A - Experimental evaluation method for reservoir matrix damage - Google Patents
Experimental evaluation method for reservoir matrix damage Download PDFInfo
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- 230000006378 damage Effects 0.000 title claims abstract description 149
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- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims abstract description 15
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- 238000006073 displacement reaction Methods 0.000 claims abstract description 13
- 238000002474 experimental method Methods 0.000 claims abstract description 12
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- 239000000706 filtrate Substances 0.000 claims description 27
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- 239000012065 filter cake Substances 0.000 claims description 14
- 239000007788 liquid Substances 0.000 claims description 13
- 239000003513 alkali Substances 0.000 claims description 12
- 229920002521 macromolecule Polymers 0.000 claims description 8
- 239000002562 thickening agent Substances 0.000 claims description 5
- 238000004458 analytical method Methods 0.000 claims description 3
- 238000007790 scraping Methods 0.000 claims description 3
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- 239000000243 solution Substances 0.000 description 23
- 239000012267 brine Substances 0.000 description 6
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- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 6
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Abstract
An experimental evaluation method of reservoir matrix damage, comprising: evacuating a rock sample, soaking the rock sample in preset simulated experiment saline water for a first preset time, putting the rock core into a holder, and adjusting the confining pressure to the preset confining pressure; reversely displacing the rock core, and measuring the reference permeability of the rock sample to obtain a first permeability; the displacement is stopped after the pore volume of a first preset amount is positively displaced by using preset active water, the temperature and pressure are kept to enable the preset active water to react with the rock sample for a second preset time, the rock core is reversely displaced by using preset simulation experiment saline, and the permeability of the rock core after the water sensitivity occurs is measured to obtain a second permeability; and determining the permeability change damage rate caused by the water sensitivity according to the first permeability and the second permeability to obtain a first permeability change damage rate. The method can realize quantitative evaluation of the fracturing fluid on the damage of the reservoir matrix, and can accurately classify the main damage and the size of the main damage in batches, so that an accurate and reliable theory and data basis can be provided for the optimization direction of the fracturing fluid.
Description
Technical Field
The invention relates to the technical field of oil and gas exploration and development, in particular to an experimental evaluation method for reservoir matrix damage.
Background
Because of the low-porosity and low-permeability reservoir characteristics of the tight sandstone gas reservoir, the economic productivity of the tight sandstone gas reservoir can be realized only by a fracturing technology. The fracturing fluid is used as an indispensable technical measure of a fracturing technology, and the invasion damage of a gel breaking liquid filtrate to a reservoir stratum is one of key factors influencing the release of production energy. The damage composition and the damage size of the fracturing fluid gel breaking liquid to the reservoir matrix are effectively evaluated, and a more reliable basis can be provided for the optimization direction of the fracturing fluid.
At present, a compact sandstone gas reservoir is usually subjected to reservoir transformation by adopting an alkaline guar water-based fracturing fluid system. And water-sensitive, alkali-sensitive and fracturing fluid gel breaking liquid filtrate core damage experiments are adopted to evaluate the damage of the fracturing fluid to the reservoir, but the sensitivity evaluation in the row standard only considers a single factor, and the damage of the gel breaking liquid filtrate core damage experiments is also total damage.
Disclosure of Invention
In order to solve the problems, the invention provides an experimental evaluation method for reservoir matrix damage, which comprises the following steps:
step one, evacuating a rock sample, soaking the rock sample in preset simulated experiment saline water for a first preset time, putting the rock core into a holder, and adjusting confining pressure to the preset confining pressure;
secondly, reversely displacing the rock core, and measuring the reference permeability of the rock sample to obtain a first permeability;
step three, utilizing preset active water to positively displace a first preset number of pore volumes, then stopping displacement, keeping the temperature and pressure to enable the preset active water to react with a rock sample for a second preset time, utilizing the preset simulation experiment saline water to reversely displace the rock core, and measuring the rock core permeability after water sensitivity occurs to obtain a second permeability;
and step four, determining the permeability change damage rate caused by the water sensitivity according to the first permeability and the second permeability to obtain a first permeability change damage rate.
According to one embodiment of the invention, after the confining pressure is adjusted to the preset confining pressure, the net confining pressure of the core is kept at the preset confining pressure in the subsequent experiment process.
According to one embodiment of the invention, the first permeability change impairment rate is determined according to the expression:
wherein eta is1Denotes the first permeability change damage rate, K1Denotes the first permeability, K2Representing the second permeability.
According to an embodiment of the invention, the method further comprises:
step five, positively displacing a second preset number of pore volumes by using preset alkaline active water, stopping displacement, preserving heat and pressure to enable the preset active water to react with a rock sample for a third preset time, reversely displacing the rock core by using the preset simulation experiment saline water, and measuring the rock core permeability after the alkaline sensitivity occurs to obtain a third permeability;
and step six, determining the permeability change damage rate caused by the alkali sensitivity according to the first permeability, the second permeability and the third permeability to obtain a second permeability change damage rate.
According to an embodiment of the invention, in the sixth step, the second permeability change impairment rate is determined according to the following expression:
wherein eta is2Denotes the second permeability change damage rate, K1Denotes the first permeability, K2Denotes the second permeability, K3Representing the third permeability.
According to an embodiment of the invention, the method further comprises:
step seven, introducing a preset gel breaking solution filtrate into the rock sample in the forward direction, stopping displacement after the outlet gel breaking solution is discharged to a third preset number of pore volumes, reversely displacing the rock core by using the preset simulation experiment saline water, and measuring the permeability of the rock core after the fracturing fluid gel breaking solution is damaged to obtain a fourth permeability;
and step eight, determining the permeability change damage rate caused by the thickening agent in the filtrate of the gel breaking solution according to the first permeability, the third permeability and the fourth permeability to obtain a third permeability change damage rate.
According to an embodiment of the invention, in the step eight, the third permeability change impairment rate is determined according to the following expression:
wherein eta is3Denotes the third permeability change damage rate, K1Denotes the first permeability, K3Denotes the third permeability, K4The fourth permeability is indicated.
According to an embodiment of the invention, the method further comprises:
scraping off filter cakes on the end face of the rock core, reversely displacing the rock core by using the preset simulation experiment saline water, and measuring the permeability of the rock core damaged by the fracturing fluid to obtain a fifth permeability;
and step ten, determining the permeability change damage rate caused by the filter cake according to the first permeability, the fourth permeability and the fifth permeability to obtain a fourth permeability change damage rate.
According to an embodiment of the invention, in the step ten, the fourth permeability change impairment rate is determined according to the following expression:
wherein eta is4Denotes the fourth permeability change impairment Rate, K1Denotes the first permeability, K4Denotes the fourth permeability, K5Representing a fifth permeability.
According to an embodiment of the invention, the method further comprises:
step eleven, determining the total damage rate of the change of the permeability of the filtrate of the gel breaking solution according to the first permeability and the fourth permeability to obtain a fifth damage rate of the change of the permeability.
According to an embodiment of the invention, the method further comprises:
and step twelve, determining the blocking damage of the macromolecules to the reservoir matrix after the filter cake is removed from the gel breaking solution filtrate according to the third permeability change damage rate and the fourth permeability change damage rate, and obtaining a sixth permeability change damage rate.
According to an embodiment of the invention, the method further comprises:
and thirteen, performing damage batching according to the first permeability change damage rate, the second permeability change damage rate, the fourth permeability change damage rate, the fifth permeability change damage rate and the sixth permeability change damage rate to correspondingly obtain the water-sensitive damage degree, the alkali-sensitive damage degree, the gel breaking liquid filtrate damage degree and the damage degree of the large analysis to the pore throats of the reservoirs.
The test evaluation method for the damage of the reservoir matrix provided by the invention can realize quantitative evaluation of the damage of the fracturing fluid to the reservoir matrix, and can accurately classify the main damage and the size of the main damage in batches, so that an accurate and reliable theory and data basis can be provided for the optimization direction of the fracturing fluid.
Additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. The objectives and other advantages of the invention will be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required in the description of the embodiments or the prior art:
FIG. 1 is a schematic flow chart of an implementation of a method for experimental evaluation of reservoir matrix damage according to one embodiment of the present invention;
FIG. 2 is a schematic flow chart of an implementation of a method for experimental evaluation of reservoir matrix damage according to an embodiment of the present invention;
figure 3 is a schematic illustration of the damage results of well fracturing fluid in accordance with one embodiment of the present invention.
Detailed Description
The following detailed description of the embodiments of the present invention will be provided with reference to the drawings and examples, so that how to apply the technical means to solve the technical problems and achieve the technical effects can be fully understood and implemented. It should be noted that, as long as there is no conflict, the embodiments and the features of the embodiments of the present invention may be combined with each other, and the technical solutions formed are within the scope of the present invention.
In the following description, for purposes of explanation, numerous specific details are set forth in order to provide a thorough understanding of the embodiments of the invention. It will be apparent, however, to one skilled in the art that the present invention may be practiced without some of these specific details or with other methods described herein.
Additionally, the steps illustrated in the flow charts of the figures may be performed in a computer system such as a set of computer-executable instructions and, although a logical order is illustrated in the flow charts, in some cases, the steps illustrated or described may be performed in an order different than here.
Although the literature reports that the water sensitivity characteristic is evaluated by an active water experiment in which the guar gum and the anionic surfactant are not added and additives in other fracturing fluid formulas are added, the batch and size experimental evaluation of various damages such as water sensitivity, alkali sensitivity and macromolecules of fracturing fluid gel breaking liquid is not reported.
Aiming at the problems in the prior art, the invention provides a novel experimental evaluation method for damage of a reservoir matrix, which can effectively divide the main damage composition and size of fracturing fluid to the reservoir matrix in batches. Fig. 1 shows a schematic flow chart of the implementation of the method in this embodiment.
As shown in fig. 1, the experimental evaluation method for matrix damage in reservoir provided in this embodiment first evacuates a rock sample and soaks the rock sample in a preset simulated experimental brine for a first preset time period in step S101, and then places the core into a holder and adjusts the confining pressure to a preset confining pressure in step S102.
Specifically, in this embodiment, the above-mentioned pre-set simulated experimental brine is pre-formulated, and it is preferably a 3% KCl solution. Of course, in other embodiments of the present invention, the solution and the solution solubility used in the preset simulated experimental saline may also be prepared according to actual needs, and the present invention is not limited thereto.
Meanwhile, in this embodiment, in step S101, the method preferably immerses the rock sample in the preset simulated experiment brine for more than 24 hours, that is, the value of the first preset time period is minimum 24 hours. Of course, in other embodiments of the present invention, the first preset time period may also take other reasonable values that are properly smaller than 24 hours (e.g., 12 hours, 16 hours, 20 hours, etc.), and the present invention also does not limit the specific value of the first preset time period.
In this embodiment, after the confining pressure is adjusted to the preset confining pressure, the method may further maintain the net confining pressure of the core at the preset confining pressure in a subsequent experiment process. For example, after placing the core into the holder, the method preferably adjusts the confining pressure to 2MPa, and during subsequent displacement tests, the method adjusts the confining pressure pump as the inlet pressure changes so that the net confining pressure is always at or near 2 MPa.
It should be noted that, in other embodiments of the present invention, the specific value of the preset confining pressure may also be configured to be other reasonable values according to actual needs, and the present invention does not limit the specific value of the preset confining pressure.
In the embodiment, as shown in fig. 1, the method reversely displaces the core in step S103 and measures the reference permeability of the rock sample, so as to obtain the first permeability K1。
The method then continues by positively displacing a first predetermined amount of pore volume with a predetermined active water in step S104, stopping the displacement, and maintaining the temperature and pressure in step S105 to react the predetermined active water with the rock sample for a second predetermined length of time.
Specifically, in this embodiment, the preset active water used in step S104 of the method is preferably pre-prepared, and the formulation thereof is preferably a fracturing fluid base fluid formulation without guar gum or sodium carbonate. Because the formula of the preset active water does not contain sodium carbonate, alkali-sensitive damage can be eliminated.
Of course, in other embodiments of the present invention, the formula of the preset active water may also adopt other reasonable formulas, and the present invention does not limit the specific formula of the preset active water.
Meanwhile, in the embodiment, the first predetermined amount is preferably selected within a range of 10 to 15PV according to actual needs, that is, the method positively displaces 10 to 15PV by using the predetermined active water in step S104. Of course, in other embodiments of the present invention, the specific value of the first preset number may also be configured to be other reasonable values according to actual needs.
In the present embodiment, the second preset time period is preferably configured to be 12 hours. Of course, in other embodiments of the present invention, according to an actual situation, the specific value of the second preset time period may also be configured to be another reasonable value that can ensure that the preset active water and the rock sample are fully reflected, and the specific value of the second preset time period is not limited in the present invention.
In this embodiment, as shown in fig. 1, in step S106, the method preferably utilizes reverse displacement of the core with the preset simulated experiment brine, and measures the permeability of the core after water sensitivity occurs, so as to obtain a second permeability K2。
At a first permeability K1And a second permeability K2Thereafter, in this embodiment, the method may also be based on the first permeability K in step S1071And a second permeability K2To determine the permeability change damage rate caused by the water sensitivity, thus obtaining a first permeability change damage rate eta1。
Specifically, in the present embodiment, the method determines the first permeability change damage rate η in step S107 preferably according to the following expression1：
Of course, in other embodiments of the present invention, the method may also adopt other methods to determine the first permeability K according to actual needs1And a second permeability K2Determining the permeability change damage rate caused by water sensitivity.
Meanwhile, it should be noted that, in this embodiment, optionally, the method may further determine other damage of the fracturing fluid to the reservoir. As shown in FIG. 2, in the present example, the permeability change damage rate η is determined1Then, the first method may further comprise, in step S201, using a preset alkaline activated water to positively displace a second preset amount of pore volumes, and then stopping the displacement, and maintaining the temperature and pressure to allow the preset activated water to react with the rock sample for a third preset time. Subsequently, the method reversely displaces the core by using the preset simulation experiment saline water in step S202, and measures the permeability of the core after the alkali sensitivity occurs, so as to obtain a third permeability K3。
In this embodiment, the preset alkaline active water is preferably a fracturing fluid base fluid formulation containing no guar gum. Of course, in other embodiments of the present invention, the predetermined alkaline active water may also adopt other reasonable formulations according to actual needs.
Meanwhile, in this embodiment, the second preset number is preferably equal to the first preset number, and the third preset duration is preferably equal to the second preset duration. Of course, in other embodiments of the present invention, the second preset number may also be configured to be other reasonable values not equal to the first preset number according to actual needs, and meanwhile, the third preset duration may also be configured to be other reasonable values not equal to the second preset duration according to actual needs.
In this example, the third permeability K is obtained3The method may also include the step of S203 determining a first permeability K1A second permeability K2And a third permeability K3To determine the rate of permeability change impairment caused by base sensitivity, thus obtaining a second rate of permeability change impairment η2。
Specifically, in the present embodiment, the method determines the second permeability change damage rate η in step S203 preferably according to the following expression2：
Of course, in other embodiments of the present invention, the method may also adopt other methods to determine the first permeability K according to actual needs1A second permeability K2And a third permeability K3Determining the permeability change damage rate caused by water sensitivity.
Optionally, in this embodiment, the method may further determine a permeability change damage rate caused by the thickener in the filtrate of the gel breaking solution. Specifically, as shown in fig. 2, in this embodiment, in step S204, the method may further include introducing a preset gel breaking solution filtrate into the rock sample in the forward direction, and after a third preset number of pores are obtained in the outlet gel breaking solution filtrate, performing pore size reductionThe displacement was stopped after the volume. Then, the method reversely displaces the core by using the preset simulation experiment saline water in step S205, and measures the permeability of the core after the fracturing fluid gel breaking liquid is damaged, so that a fourth permeability K is obtained4。
In this embodiment, the predetermined gel breaking solution filtrate is preferably obtained by filtering the filtrate after breaking the fracturing fluid with a filter membrane having a certain pore (for example, 3 μm). The third predetermined amount is preferably configured to be 10, i.e. the method stops the displacement after the outlet of the gel breaking liquid 10PV in step S204. Of course, in other embodiments of the present invention, the specific value of the third preset number may also be configured to be other reasonable values according to actual needs.
In this example, the fourth permeability K is obtained4The method may then proceed to step S206 based on the first permeability K1A third permeability K3And a fourth permeability K4Determining the damage rate of permeability change caused by the thickening agent in the filtrate of the gel breaking solution to obtain a third damage rate eta of permeability change3。
Specifically, in the present embodiment, the method determines the third permeability change damage rate η in step S206 preferably according to the following expression3：
Of course, in other embodiments of the present invention, the method may also adopt other ways to determine the first permeability K according to actual needs1A third permeability K3And a fourth permeability K4Determining a third permeability change damage rate η3The present invention is not limited thereto.
Optionally, in this embodiment, the method may further determine the permeability change damage rate caused by the filter cake. Specifically, as shown in fig. 2, in this embodiment, in step S207, the method scrapes off a filter cake on an end face of the core, reversely displaces the core by using the preset simulation experiment brine, and measures the damaged rock by the fracturing fluidHeart permeability, thereby obtaining a fifth permeability K5。
At a fifth permeability K5Thereafter, the method proceeds to step S208 where the first permeability K is obtained1Fourth permeability K4And a fifth permeability K5To determine the permeability change impairment rate caused by the filter cake, and thus obtaining a fourth permeability change impairment rate eta4。
Specifically, in the present embodiment, the method determines the fourth permeability change damage rate η in step S208 preferably according to the following expression4：
In this example, the first permeability K is obtained1And a fourth permeability K4Thereafter, the method may also include in step S209, based on the first permeability K described above1And a fourth permeability K4Determining the total damage rate of the change of the permeability of the filtrate of the gel breaking solution, thereby obtaining the fifth damage rate eta of the change of the permeability5。
Specifically, in the present embodiment, the method determines the fifth permeability change damage rate η in step S209 preferably according to the following expression5：
Of course, in other embodiments of the invention, the method may also determine the total damage rate of the permeability change of the filtrate of the gel breaking solution (i.e., the fifth damage rate η of permeability change) in other reasonable manners5)。
In addition, in this embodiment, the method may optionally determine plugging damage of the macromolecule to the reservoir matrix after removal of the filter cake. As shown in FIG. 2, in the present embodiment, the method changes the damage rate η according to the obtained third permeability in step S2103And fourth permeability change damage rate eta4To determine the brokenRemoving filter cakes from the glue solution filtrate to prevent the macromolecule from damaging the reservoir matrix, thereby obtaining a sixth permeability change damage rate eta6。
Specifically, in the present embodiment, the method may preferably determine the sixth permeability change damage rate η according to the following expression in step S2106：
η6＝η3-η4 (6)
Meanwhile, besides determining the damage rate of various permeability changes, according to actual needs, the method can also determine damage batch classification of various permeability changes. As shown in fig. 2, in the present embodiment, the method may change the damage rate η according to the obtained first permeability in step S2111Second permeability change damage rate eta2Fourth permeability change damage η4Fifth permeability change damage η5And sixth permeability change damage rate eta6And carrying out injury classification, and correspondingly obtaining the water-sensitive injury degree, the alkali-sensitive injury degree, the injury degree of the filtrate of the gel breaking liquid and the injury degree of the pore throat of the reservoir by large analysis.
Wherein the degree of water-sensitive damage m1Preferably, it can be calculated according to the following expression:
degree of alkali-sensitive damage m2Preferably, it can be calculated according to the following expression:
damage degree m of gel breaking liquid filter cake4Preferably, it can be calculated according to the following expression:
degree m of damage of macromolecules to pore throats of reservoirs6Preferably, it can be calculated according to the following expression:
in order to prove the availability and reliability of the experimental evaluation method for the reservoir matrix damage provided by the invention, the core of a certain well is adopted, and the method is utilized to polar the evaluation experiment of the reservoir matrix damage. Table 1 shows the corresponding test results.
TABLE 1
| Type of fluid | Symbol of permeability | Permeability (mD) |
| After initial test brine passage | K1 | 0.1342 |
| After the active water passes through | K2 | 0.0993 |
| After alkaline active water passes through | K3 | 0.0937 |
| After fracturing fluid gel breaking liquid passes through | K4 | 0.0812 |
| After filtering and scraping | K5 | 0.0892 |
From the data set forth in Table 1, the permeability change rate damage due to water sensitivity, i.e., the first permeability change rate damage η, can be calculated1：
Permeability change impairment rate due to alkali sensitivity, i.e. second permeability change impairment rate eta2：
Permeability change damage rate caused by thickening agent in gel breaking solution filtrate, i.e. third permeability change damage rate eta3：
The damage rate of permeability change caused by cake after damage of filtrate of gel breaking solution, namely the fourth damage rate eta of permeability change4：
The total damage rate of the filtrate of the gel breaking solution, i.e. the fifth damage rate of the filtrate of the gel breaking solution5：
Removing filter cake to prevent the blockage damage of macromolecule to the reservoir matrix, i.e. the sixth permeability change damage rate eta6：
η6＝η3-η4＝3.3％ (16)
Finally, the water-sensitive damage degree m can be obtained by dividing the damage sizes1：
Degree of alkali-sensitive damage m2：
Damage degree m of gel breaking liquid filter cake4：
Degree m of damage of macromolecules to pore throats of reservoirs6：
The pressure fluid damage results plot for this well may be represented as shown in figure 3.
From the description, the experimental evaluation method for the damage of the reservoir matrix provided by the invention can realize quantitative evaluation of the damage of the fracturing fluid to the reservoir matrix, and can accurately classify the main damage and the size of the main damage in batches, so that an accurate and reliable theory and data basis can be provided for the optimization direction of the fracturing fluid.
It is to be understood that the disclosed embodiments of the invention are not limited to the particular structures or process steps disclosed herein, but extend to equivalents thereof as would be understood by those skilled in the relevant art. It is also to be understood that the terminology used herein is for the purpose of describing particular embodiments only, and is not intended to be limiting.
Reference in the specification to "one embodiment" or "an embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Thus, the appearances of the phrase "one embodiment" or "an embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment.
While the above examples are illustrative of the principles of the present invention in one or more applications, it will be apparent to those of ordinary skill in the art that various changes in form, usage and details of implementation can be made without departing from the principles and concepts of the invention. Accordingly, the invention is defined by the appended claims.
Claims (12)
1. An experimental evaluation method for reservoir matrix damage, the method comprising:
step one, evacuating a rock sample, soaking the rock sample in preset simulated experiment saline water for a first preset time, putting the rock core into a holder, and adjusting confining pressure to the preset confining pressure;
secondly, reversely displacing the rock core, and measuring the reference permeability of the rock sample to obtain a first permeability;
step three, utilizing preset active water to positively displace a first preset number of pore volumes, then stopping displacement, keeping the temperature and pressure to enable the preset active water to react with a rock sample for a second preset time, utilizing the preset simulation experiment saline water to reversely displace the rock core, and measuring the rock core permeability after water sensitivity occurs to obtain a second permeability;
and step four, determining the permeability change damage rate caused by the water sensitivity according to the first permeability and the second permeability to obtain a first permeability change damage rate.
2. The method of claim 1, wherein after adjusting the confining pressure to the preset confining pressure, a net confining pressure of the core is maintained at the preset confining pressure during a subsequent experiment.
3. The method of claim 1 or 2, wherein the first permeability change impairment rate is determined according to the expression:
wherein eta is1Denotes the first permeability change damage rate, K1Denotes the first permeability, K2Representing the second permeability.
4. The method of any one of claims 1 to 3, further comprising:
step five, positively displacing a second preset number of pore volumes by using preset alkaline active water, stopping displacement, preserving heat and pressure to enable the preset active water to react with a rock sample for a third preset time, reversely displacing the rock core by using the preset simulation experiment saline water, and measuring the rock core permeability after the alkaline sensitivity occurs to obtain a third permeability;
and step six, determining the permeability change damage rate caused by the alkali sensitivity according to the first permeability, the second permeability and the third permeability to obtain a second permeability change damage rate.
5. The method of claim 4, wherein in step six, the second permeability change impairment rate is determined according to the expression:
wherein eta is2Denotes the second permeability change damage rate, K1Denotes the first permeability, K2Denotes the second permeability, K3Representing the third permeability.
6. The method of claim 4 or 5, wherein the method further comprises:
step seven, introducing a preset gel breaking solution filtrate into the rock sample in the forward direction, stopping displacement after the outlet gel breaking solution is discharged to a third preset number of pore volumes, reversely displacing the rock core by using the preset simulation experiment saline water, and measuring the permeability of the rock core after the fracturing fluid gel breaking solution is damaged to obtain a fourth permeability;
and step eight, determining the permeability change damage rate caused by the thickening agent in the filtrate of the gel breaking solution according to the first permeability, the third permeability and the fourth permeability to obtain a third permeability change damage rate.
7. The method of claim 6 wherein in step eight, the third permeability change impairment rate is determined according to the expression:
wherein eta is3Denotes the third permeability change damage rate, K1Denotes the first permeability, K3Denotes the third permeability, K4The fourth permeability is indicated.
8. The method of claim 6 or 7, wherein the method further comprises:
scraping off filter cakes on the end face of the rock core, reversely displacing the rock core by using the preset simulation experiment saline water, and measuring the permeability of the rock core damaged by the fracturing fluid to obtain a fifth permeability;
and step ten, determining the permeability change damage rate caused by the filter cake according to the first permeability, the fourth permeability and the fifth permeability to obtain a fourth permeability change damage rate.
9. The method of claim 8 wherein in said step ten, said fourth permeability change impairment rate is determined according to the expression:
wherein eta is4Denotes the fourth permeability change impairment Rate, K1Denotes the first permeability, K4Denotes the fourth permeability, K5Representing a fifth permeability.
10. The method of claim 8 or 9, wherein the method further comprises:
step eleven, determining the total damage rate of the change of the permeability of the filtrate of the gel breaking solution according to the first permeability and the fourth permeability to obtain a fifth damage rate of the change of the permeability.
11. The method of claim 10, wherein the method further comprises:
and step twelve, determining the blocking damage of the macromolecules to the reservoir matrix after the filter cake is removed from the gel breaking solution filtrate according to the third permeability change damage rate and the fourth permeability change damage rate, and obtaining a sixth permeability change damage rate.
12. The method of claim 11, wherein the method further comprises:
and thirteen, performing damage batching according to the first permeability change damage rate, the second permeability change damage rate, the fourth permeability change damage rate, the fifth permeability change damage rate and the sixth permeability change damage rate to correspondingly obtain the water-sensitive damage degree, the alkali-sensitive damage degree, the gel breaking liquid filtrate damage degree and the damage degree of the large analysis to the pore throats of the reservoirs.
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