CN112396261A - Method and device for evaluating influence of carbonate rock acidification modification on reserve calculation result - Google Patents
Method and device for evaluating influence of carbonate rock acidification modification on reserve calculation result Download PDFInfo
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- 238000004364 calculation method Methods 0.000 title claims abstract description 40
- 230000020477 pH reduction Effects 0.000 title claims abstract description 33
- 238000000034 method Methods 0.000 title claims abstract description 30
- 238000012986 modification Methods 0.000 title claims abstract description 21
- 230000004048 modification Effects 0.000 title claims abstract description 21
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 20
- 239000011435 rock Substances 0.000 title claims description 29
- 239000012530 fluid Substances 0.000 claims abstract description 133
- 230000008859 change Effects 0.000 claims abstract description 56
- 238000012216 screening Methods 0.000 claims abstract description 22
- 238000011156 evaluation Methods 0.000 claims abstract description 11
- 239000008398 formation water Substances 0.000 claims description 43
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 42
- 230000033558 biomineral tissue development Effects 0.000 claims description 29
- 238000012360 testing method Methods 0.000 claims description 29
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 20
- 239000002253 acid Substances 0.000 claims description 14
- 230000015572 biosynthetic process Effects 0.000 claims description 12
- 230000000717 retained effect Effects 0.000 claims description 4
- 239000000376 reactant Substances 0.000 claims description 3
- 238000012935 Averaging Methods 0.000 claims description 2
- 238000004891 communication Methods 0.000 claims description 2
- 230000008569 process Effects 0.000 abstract description 8
- 239000007789 gas Substances 0.000 description 33
- 238000006243 chemical reaction Methods 0.000 description 29
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 16
- 238000005755 formation reaction Methods 0.000 description 11
- 229910002092 carbon dioxide Inorganic materials 0.000 description 8
- 239000001569 carbon dioxide Substances 0.000 description 7
- 229910021645 metal ion Inorganic materials 0.000 description 5
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical group [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 4
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- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 2
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 2
- TWRXJAOTZQYOKJ-UHFFFAOYSA-L Magnesium chloride Chemical compound [Mg+2].[Cl-].[Cl-] TWRXJAOTZQYOKJ-UHFFFAOYSA-L 0.000 description 2
- 241001494479 Pecora Species 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 229910000019 calcium carbonate Inorganic materials 0.000 description 2
- 239000001110 calcium chloride Substances 0.000 description 2
- 229910001628 calcium chloride Inorganic materials 0.000 description 2
- 238000011161 development Methods 0.000 description 2
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- 241001114003 Seira Species 0.000 description 1
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- HHSPVTKDOHQBKF-UHFFFAOYSA-J calcium;magnesium;dicarbonate Chemical group [Mg+2].[Ca+2].[O-]C([O-])=O.[O-]C([O-])=O HHSPVTKDOHQBKF-UHFFFAOYSA-J 0.000 description 1
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- G06—COMPUTING; CALCULATING OR COUNTING
- G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
- G06Q10/00—Administration; Management
- G06Q10/06—Resources, workflows, human or project management; Enterprise or organisation planning; Enterprise or organisation modelling
- G06Q10/063—Operations research, analysis or management
- G06Q10/0639—Performance analysis of employees; Performance analysis of enterprise or organisation operations
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
- G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
- G06Q50/02—Agriculture; Fishing; Mining
Abstract
The invention relates to the field of oil and gas exploration, in particular to a method and a device for evaluating the influence of carbonate acidizing reconstruction on reserve calculation results, wherein the method comprises the following steps: extracting a fluid sample, and screening the fluid sample; comparing the average data of the screened fluid sample with the area real data, and calculating to obtain an average absolute difference value, wherein the average absolute difference value is the difference value between the average data of the screened fluid sample and the area real data, and the ratio of the average absolute difference value to the area real data is the change rate of the fluid sample; and calculating according to the change rate of the fluid sample to obtain a reserve change influence rate, wherein the reserve change influence rate is used for representing the influence degree of acidification modification on a reserve calculation result. According to the evaluation method provided by the invention, after the fluid sample is preliminarily screened, the difference value between the screened fluid sample data and the area real data is used as the basis for evaluating the influence of the acidification process, and the influence rate of the storage change can be obtained, so that the evaluation method is used for evaluating the influence of the acidification process on the storage calculation.
Description
Technical Field
The invention relates to the field of oil and gas exploration, in particular to a method and a device for evaluating the influence of carbonate acidizing reconstruction on reserve calculation results.
Background
In the process of exploration of an oil and gas reservoir, artificial cracks of a certain scale can be formed through fracturing and acidizing construction, natural gas seepage conditions are communicated and improved, near-well pollution is eliminated, the effective supply radius of natural gas is increased, the real gas content of the reservoir is evaluated, and the purposes of fully modifying the reservoir and improving the overall recovery ratio of the gas reservoir are achieved. For carbonate formations, the main constituents are dolomite and limestone. Wherein the main component of the limestone is calcium carbonate, and the main component of the dolomite is calcium magnesium carbonate. The chemical reaction formulas of the two and hydrochloric acid are respectively:
limestone: 2HCl + CaCO3→CaCl2+H2O+CO2↑
Dolomitic rock: 4HCl + CaMg (CO)3)2→CaCl2+MgCl2+2H2O+2CO2↑
From the above equation, after the reaction, a large amount of metal ions are generated in the liquid: ca2+With Mg2+The gas phase generates a large amount of carbon dioxide (CO)2). The acid rock reaction can generate great influence on the analysis data of the water sample and the gas sample, thereby influencing the correct recognition and evaluation of the reservoir, further influencing the reserve calculation result, further bringing greater development scheme, investment decision and final gas reservoir developmentAnd the economic benefit is negatively influenced.
In the prior art, the reserve is usually calculated as follows: the skilled person empirically excludes samples that are significantly different from other samples in the same area, and then calculates the reserves based on the screened samples. However, after the screening in this way, there are still more influences of the acid-rock reaction in the remaining samples, and how to eliminate the influence of the acid-rock reaction on the fluid sample and further correctly estimate the reserve volume is a problem to be solved urgently in exploration and development of carbonate reservoirs.
Disclosure of Invention
The invention aims to solve the problem that in the prior art, the reaction of acid rock influences the analysis data of a fluid sample, so that the reserve calculation result is inaccurate, and provides an evaluation method and device for the influence of acidification and modification of carbonate rock on the reserve calculation result.
In order to achieve the above purpose, the invention provides the following technical scheme:
the method for evaluating the influence of carbonate rock acidification modification on the reserve calculation result is carried out after the reservoir is subjected to acidification modification, and comprises the following steps of:
screening a fluid sample;
comparing the data average value of the screened fluid sample with the area real data, and calculating to obtain an average absolute difference value, wherein the average absolute difference value is the difference value between the average data of the screened fluid sample and the area real data, and the ratio of the average absolute difference value to the area real data is the change rate of the fluid sample;
and calculating according to the change rate of the fluid sample to obtain a reserve change influence rate, wherein the reserve change influence rate is used for representing the influence degree of acidification modification on a reserve calculation result.
When calculating reserves after acidizing and modifying carbonate rock, fluid samples with obvious errors can be screened. However, after the screening is finished, the remaining samples still have more fluid samples affected by the acidification process, so that the reliability of the reserve calculation result is poor. According to the evaluation method provided by the invention, after the fluid sample is extracted, the fluid sample is primarily screened, and the difference value between the screened fluid sample data and the area real data is used as the basis for evaluating the influence of the acidification process, so that the influence rate of the reserve change can be calculated, and the influence of the acidification process on the reserve calculation is evaluated through the influence rate of the reserve change.
In a preferred embodiment of the present invention, in the step of screening the fluid sample, the screening criteria include the methane content and/or the formation water salinity of the fluid sample.
In a preferred embodiment of the present invention, in the step of screening the fluid samples, the fluid samples with absolute differences within a preset range are retained, where the absolute differences are differences between data of a certain fluid sample and the area real data.
As a preferred embodiment of the present invention, the preset range is: the ratio of the absolute difference of the salinity of the formation water to the real data of the region is less than 30 percent, and the ratio of the absolute difference of the methane content to the real data of the region is less than 30 percent.
As a preferred embodiment of the present invention, in extracting a fluid sample: samples are taken simultaneously in multiple test wells, and for the same test well, multiple fluid samples are taken sequentially. When the fluid samples are extracted, the multiple fluid samples are sequentially extracted from the same test well, so that the condition of the acidification reaction can be observed according to the data change trend of the fluid samples in the same test well, and the judgment of whether the acidification reaction is complete or not can be facilitated.
As a preferred embodiment of the present invention, the region truth data is obtained by: after the fluid samples are screened, for a plurality of fluid samples extracted successively in the same test well, if the data change trend of the plurality of continuously extracted fluid samples tends to be stable, the data of the fluid samples in all the test wells are averaged, and the average value is regarded as area real data.
For the same test well, if the data change of the fluid sample tends to be stable along with the time, the acidification reaction is stable in the test well, the acidification reaction is gradually complete along with the time, and after the data of the fluid sample are stable, the metal ions and/or gas generated by the acidification reaction are completely discharged, so that the fluid sample can be used for real data of a reaction area.
As a preferred scheme of the invention, the regional real data of the formation water mineralization are obtained by the following modes:
and selecting a typical water layer well, extracting a water sample in the water layer well after acid rock reactant is fully discharged, and taking the formation water mineralization degree of the fluid sample of the typical water layer well as real data of the area.
As a preferred scheme of the invention, after the mineralization degree data of the fluid sample is obtained, the resistivity of formation water is obtained according to the mineralization degree query of formation water, and the original gas saturation data is calculated by using a supersaturation model, so that the influence rate of reserve volume change is obtained;
the calculation method for calculating the gas saturation through the resistivity comprises the following steps:
wherein R iswThe resistivity of the formation water can be obtained based on data query of a fluid sample; rt is the true formation resistivity; phi is the porosity; a. b is a lithology coefficient; m is a cementation index; n is a saturation index; swnThe water saturation; 1-SwnThe gas saturation is obtained, and the gas saturation change rate is equal to the reserve change influence rate.
An evaluation device for evaluating the influence of carbonate acidizing modification on reserve calculation results comprises at least one processor and a memory which is in communication connection with the at least one processor; the memory stores instructions executable by the at least one processor to enable the at least one processor to perform the method described above.
Compared with the prior art, the invention has the beneficial effects that: according to the evaluation method for the influence of the carbonate rock acidification modification on the reserve calculation result, provided by the invention, the fluid is preliminarily screened, data which obviously cannot represent the real condition of the area is eliminated, the remaining fluid samples are compared with the real condition of the area to obtain the change rate of the fluid sample, and further obtain the influence rate of the reserve change, so that the influence of the acidification modification on the reserve change influence rate can be quantitatively evaluated through the numerical value of the reserve change influence rate.
Description of the drawings:
FIG. 1 is a query chart for obtaining resistivity of formation water according to the mineralization rate of formation water.
Detailed Description
The present invention will be described in further detail with reference to test examples and specific embodiments. It should be understood that the scope of the above-described subject matter is not limited to the following examples, and any techniques implemented based on the disclosure of the present invention are within the scope of the present invention.
Examples
The embodiment of the invention provides an evaluation method for the influence of acidizing and modifying of carbonate rock on reserve calculation results, which comprises the following steps:
s100, extracting a fluid sample, and screening the fluid sample;
specifically, when a fluid sample is extracted, the sample is extracted from a plurality of test wells simultaneously, and a plurality of fluid samples are extracted from the same test well sequentially.
In screening a fluid sample:
and reserving the fluid sample with the absolute difference value within a preset range, and screening out the rest fluid samples. Wherein the absolute difference is a difference between data of a certain fluid sample and the area real data.
The preset range may be set according to the accuracy requirement of the actual calculation, for example, the preset range may be set as follows: the ratio of the absolute difference of the salinity of the formation water to the real data of the region is less than 30 percent, and the ratio of the absolute difference of the methane content to the real data of the region is less than 30 percent.
The reason why the fluid sample that is not within the preset range is excluded is that: the data of the fluid sample which is not in the preset range is quite obviously different from the data of the real condition of the stratum or other fluid samples, and a person skilled in the art can directly judge that the acid rock reaction in the test well where the fluid sample is located is not complete according to the data, so that the data is not meaningful for carrying out reserve calculation.
In addition to this, the screening out of the fluid sample can also be carried out by:
for fluid samples extracted successively from the same well, if the formation water mineralization is gradually increased along with the delay of time, the acid rock reaction is in progress, and the fluid samples in the test well are not reserved; (ii) a
For fluid samples extracted successively from the same test well, if the water salinity of the geological formation is rapidly reduced along with the delay of time, metal ions generated by acid rock reaction are not completely eliminated, and the fluid samples in the test well are not reserved;
for fluid samples extracted successively from the same test well, if the methane content and the carbon dioxide content in the gas tend to be stable along with the time delay, for example, for a plurality of fluid samples taken later from the same test well, the change range of the methane content is within 3%, the acid rock reaction is finished or basically finished, and the fluid samples are retained.
S200, comparing the average data of the screened fluid sample with the real area data, and calculating to obtain an average absolute difference value, wherein the average absolute difference value is the difference value between the average data of the screened fluid sample and the real area data, and the ratio of the average absolute difference value to the real area data is the change rate of the fluid sample;
wherein the average data for the fluid sample comprises an average number of formation water mineralization for the fluid sample and an average number of methane contents for the fluid sample;
the regional truth data is used in the reaction region when it is not affected by the acidification reaction. The mean absolute difference can then be used to evaluate the extent to which the screened fluid sample is affected by the acidification reaction.
The formation truth data can be obtained by the following modes:
after screening the fluid samples, comparing the plurality of fluid samples extracted successively in the same test well, and if the data change trend of the plurality of fluid samples extracted successively tends to be stable, averaging the data of the fluid samples in all the test wells, and regarding the averaged value as area real data.
For example, for a plurality of fluid samples taken later in the same test well, if the change range of the formation water mineralization is within 3%, the acid rock reaction is finished or basically finished, and the fluid samples are reserved; for a plurality of fluid samples taken from the same test well later, if the variation range of the methane content is within 3 percent, the acid rock reaction is finished or basically finished, and the fluid samples are reserved;
in practice, the skilled person can adjust the range of variation of the fluid sample data to be retained according to the need of calculation accuracy. For example, when the calculation accuracy requirement is high, the formation water mineralization and/or the methane content need to be evaluated more accurately, and the allowable fluid sample data variation range can be reduced; when the requirement of accurate calculation precision is low, the allowable variation range of the fluid sample data can be properly adjusted.
Or the regional real data of the formation water mineralization can be obtained by the following modes:
and selecting a water layer well, extracting a fluid sample in the water layer well, and taking the formation water mineralization degree of the fluid sample of the water layer well as the real data of the region.
S300, calculating according to the change rate of the fluid sample to obtain a reserve change influence rate, wherein the reserve change influence rate is used for representing the influence degree of acidification modification on a reserve calculation result;
specifically, after the change rate of the fluid sample is obtained, the formation water resistivity is obtained according to the formation water mineralization degree lookup table shown in fig. 1, so that the change rate of the formation water resistivity is obtained;
in fig. 1, the left ordinate is resistivity, the right ordinate is mineralization, and the bottom abscissa is temperature.
The calculation method of the reserve change influence rate comprises the following steps:
after obtaining the mineralization data of the fluid sample, inquiring according to the mineralization of the formation water to obtain the resistivity of the formation water, and calculating the original gas saturation data through a supersaturation model to obtain the influence rate of the reserve volume change;
the calculation method for calculating the gas saturation through the formation water resistivity comprises the following steps:
wherein R iswThe resistivity of the formation water can be obtained based on data query of a fluid sample; rt is the true formation resistivity; phi is the porosity; a. b is a lithology coefficient; m is a cementation index; n is a saturation index; swnTo the degree of water saturation, 1-SwnThe gas saturation is obtained, and when other parameters are kept unchanged, the gas saturation change rate is equal to the reserve change influence rate.
The invention is illustrated below by means of a calculation example:
taking the analysis of the reserves of the acid-modified mine four gas reservoir in the exploration area of western Sichuan as an example. Table 1 shows the water sample analysis data for the four gas reservoirs in west chuan.
TABLE 1 Sichuan-xi-Lei-four gas reservoir water sample analysis data sheet
S100, extracting a fluid sample, and screening the fluid sample;
as can be seen from table 1, the data of the pengzhou 115 well and the duck deep 1 well are greatly different from those of other wells and are first excluded. Next, in the initial stages of the pengzhou 103 well reaction, i.e. 11 and 30 days in 2017, the mineralization was significantly reduced in two different samples taken on the same day, indicating that the well was being depleted of metal ions produced by the acidification reaction, and therefore the fluid sample of the pengzhou 103 well at 11 and 30 days in 2017 was depleted. The rest fluid sample is the screened fluid sample;
s200, comparing the data average value of the screened fluid sample with the area real data, and calculating to obtain an average absolute difference value, wherein the average absolute difference value is the difference value between the screened fluid sample average data and the area real data, and the ratio of the average absolute difference value to the area real data is the change rate of the fluid sample;
the region real data is obtained by the following method: the Tong deep 1 well is a typical water layer well, and the formation water mineralization degree of the well has certain representativeness and can be used as a calculation basis of real data of a region; the pengzhou 103 well is reacted to the later stage (12 and 05 in 2017), the formation water mineralization is basically stable, which indicates that metal ions generated by acidification are completely or basically completely discharged, so that the formation water mineralization of the pengzhou 103 well fluid sample in 12 and 5 in 2017 can reflect the real data of the formation. The above four data were averaged to obtain the true formation data of formation water mineralization in this example, which was 118160 mg/l.
The average of the formation water mineralization of the fluid samples obtained after screening in S100 was 128627.8118160 mg/l.
The average absolute difference is 10467.9 mg/l.
S300, calculating according to the change rate of the fluid sample to obtain a reserve change influence rate, wherein the reserve change influence rate is used for representing the influence degree of acidification modification on a reserve calculation result;
according to the mineralization degree of the formation water, the resistivity of the formation water is obtained through query according to a query table shown in the figure, and therefore the change rate of the resistivity of the formation water can be obtained;
the method for calculating the influence rate of reserve change based on the change rate of the formation water resistivity comprises the following steps:
after obtaining the mineralization data of the fluid sample, inquiring according to the mineralization of the formation water to obtain the resistivity of the formation water, and calculating the original gas saturation data through a supersaturation model to obtain the influence rate of the reserve volume change;
the calculation method for calculating the gas saturation through the formation water resistivity comprises the following steps:
wherein R iswIs groundThe formation water resistivity can be obtained based on the data query of the fluid sample; rt is the true formation resistivity; phi is the porosity; a. b is a lithology coefficient; m is a cementation index; n is a saturation index; swnThe water saturation; 1-SwnThe obtained numerical value is the gas saturation, and when other parameters are kept unchanged, the gas saturation change rate is equal to the reserve change influence rate numerical value.
Table 2 shows the analysis data of the gas sample of the seira chuangsi gas reservoir.
TABLE 2 analysis data table of four gas reservoirs of Sichuan-xi-Lei
S100, extracting a fluid sample, and screening the fluid sample;
as can be seen from Table 1, the methane content in the Xiao Shen 1 well is greatly different from that of other wells, so that the data of the Xiao Shen 1 well are excluded.
S200, comparing the average data of the screened fluid sample with the real area data, and calculating to obtain an average absolute difference value, wherein the average absolute difference value is the difference value between the average data of the screened fluid sample and the real area data, and the ratio of the average absolute difference value to the real area data is the change rate of the fluid sample;
the region real data can be obtained by the following method:
for Pengzhou 1 well, the flowback rate is as low as 19.8%, which indicates that acid is bound in the reservoir, reactants enter the shaft and are discharged little, and the discharge rate is 73.5X 104m3Meanwhile, the gas sample analysis result is not much different from other test wells in the region, so that the gas sample of the Pengzhou 1 well can represent the real data of the region;
for 1 well with deep duck, the data collected in 7/12/2015 is highly consistent with the gas sample data collected in 7/4/2018, and has no obvious difference with other test wells in the region, which indicates that the acidification reaction has completely reacted in 7/12/2015. Data collected by 1-well duck 2015, 12 days in 7 months and 7 days in 2018, 4 months and 7 days can represent real data of the region;
for the sheep deep 1 well, the data acquired in three times are highly consistent, the maximum error is within 3%, and the three data of the sheep deep 1 well can represent the real data of the stratum.
For the Pengzu 103 well, the methane content gradually increased with time delay and the carbon dioxide content gradually decreased with time delay, indicating that the effect of acid rock reaction on the gas sample is still in progress, which cannot represent the true data of the stratum.
For the chuan family 1 well, the methane content and carbon dioxide content were stable in the samples collected from 6/7/2010 to 6/28/2010, indicating that the effect of the acid rock reaction on the gas sample has ended, which may represent formation truth data.
For the new deep 1 well and the horse well 1, the methane content gradually increases along with the time delay, which indicates that the influence of acid rock reaction on the gas sample is not finished and the true data of the stratum cannot be represented.
After S100 screening, the average methane content of the obtained fluid samples is 86.95%, the average methane content of the fluid samples which can represent the true data of the formation is 90.98%, and the average absolute difference of the methane content is 4.03%.
After S100 screening, the average carbon dioxide content of the obtained fluid samples is 9.47%, the average methane content of the fluid samples which can represent the real data of the formation is 5.11%, and the average absolute difference of the carbon dioxide content is 4.36%.
In this example, the calculated methane reserves were reduced by 4.03% and the calculated carbon dioxide reserves were increased by 4.36% after the acidizing modification.
The evaluation method for the influence of the acidizing modification of the carbonate rock on the reserve calculation result has the beneficial effects that:
1. according to the evaluation method provided by the invention, after the fluid sample is preliminarily screened, the difference value between the screened fluid sample data and the area real data is used as the basis for evaluating the influence of the acidification process, so that the influence rate of the reserve change can be calculated, and the influence of the acidification process on the reserve calculation is evaluated through the influence rate of the reserve change;
2. when the fluid samples are extracted, the multiple fluid samples are sequentially extracted from the same test well, so that the condition of the acidification reaction can be observed according to the data change trend of the fluid samples in the same test well, and the judgment of whether the acidification reaction is complete or not can be facilitated.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents and improvements made within the spirit and principle of the present invention are intended to be included within the scope of the present invention.
Claims (9)
1. The method for evaluating the influence of carbonate rock acidification reformation on the reserve calculation result is characterized by being carried out after the reservoir stratum is subjected to acidification reformation and comprising the following steps of:
screening a fluid sample;
comparing the data average value of the screened fluid sample with the area real data, and calculating to obtain an average absolute difference value, wherein the average absolute difference value is the difference value between the screened fluid sample average data and the area real data, and the ratio of the average absolute difference value to the area real data is the change rate of the fluid sample;
and calculating according to the change rate of the fluid sample to obtain a reserve change influence rate, wherein the reserve change influence rate is used for representing the influence degree of acidification modification on a reserve calculation result.
2. The method of claim 1, wherein in the step of screening the fluid sample, the screening criteria include methane content and/or formation water mineralization of the fluid sample.
3. The method of claim 2, wherein in the step of screening the fluid samples, the fluid samples with absolute differences within a predetermined range are retained, wherein the absolute differences are differences between data of a certain fluid sample and real data of a region.
4. The method for evaluating the influence of acidizing modification of carbonate rock on reserve calculation results according to claim 3, wherein the preset range is as follows: the ratio of the absolute difference of the salinity of the formation water to the real data of the region is less than 30 percent, and the ratio of the absolute difference of the methane content to the real data of the region is less than 30 percent.
5. Method for the evaluation of the impact of carbonate acidizing modifications on reserve calculations according to any of the claims 1 to 4, characterized in that in the extracted fluid sample:
samples are taken simultaneously in multiple test wells, and for the same test well, multiple fluid samples are taken sequentially.
6. The method for evaluating the influence of acidizing modification on reserve calculation results of carbonate rock according to claim 5, wherein the regional truth data is obtained by the following method:
after screening the fluid samples, comparing the plurality of fluid samples extracted successively in the same test well, and if the data change trend of the plurality of fluid samples extracted successively tends to be stable, averaging the data of the fluid samples in all the test wells, and regarding the averaged value as area real data.
7. The method for evaluating the influence of acidizing modification of carbonate rock on reserve calculation results according to any one of claims 1 to 4, wherein the regional true data of the formation water mineralization are obtained by the following method:
and selecting a typical water layer well, extracting a water sample in the water layer well after acid rock reactant is fully discharged, and taking the formation water mineralization degree of the fluid sample of the typical water layer well as real data of the area.
8. The method for evaluating the influence of acidizing reconstruction of carbonate rock on the reserve calculation result according to claim 1, wherein after the mineralization degree data of the fluid sample is obtained, the resistivity of formation water is obtained through inquiry according to the mineralization degree of formation water, and then the original gas saturation data is calculated through a supersaturation degree model, so that the influence rate of the reserve change is obtained;
the calculation method for calculating the gas saturation through the resistivity of the reserves comprises the following steps:
wherein R iswThe resistivity of the formation water can be obtained based on data query of a fluid sample; rt is the true formation resistivity; phi is the porosity; a. b is a lithology coefficient; m is a cementation index; n is a saturation index; swnThe water saturation; 1-SwnThe obtained numerical value is the gas saturation, and when other parameters are kept unchanged, the gas saturation change rate is equal to the reserve change influence rate numerical value.
9. The device for evaluating the influence of carbonate acidizing modification on reserve calculation results is characterized by comprising at least one processor and a memory which is in communication connection with the at least one processor; the memory stores instructions executable by the at least one processor to enable the at least one processor to perform the method of any one of claims 1 to 8.
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