CN114428088B - Method for generating hydrocarbon source fluid corrosion hole-increasing capability evaluation plate - Google Patents
Method for generating hydrocarbon source fluid corrosion hole-increasing capability evaluation plate Download PDFInfo
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- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
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- G01N2223/05—Investigating materials by wave or particle radiation by diffraction, scatter or reflection
- G01N2223/056—Investigating materials by wave or particle radiation by diffraction, scatter or reflection diffraction
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
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Abstract
The invention provides a method for generating a hydrocarbon source fluid corrosion hole-increasing capacity evaluation plate, which comprises the following steps: analyzing the geological features of the research area to determine a representative well, a hydrocarbon source rock sample or a surrogate thereof, and a reservoir sample or a surrogate thereof; setting experimental parameters, and carrying out an acid generation experiment of the hydrocarbon source rock; testing the content of organic acid, and calculating the acid generating capacity of the hydrocarbon source rock; calculating a theoretical erosion increase Kong Liang; and (5) changing experimental parameters to obtain corrosion increase Kong Liang under different conditions, and generating corresponding evaluation plates. The method for generating the evaluation chart of the corrosion hole-increasing capability of the hydrocarbon source fluid under the geological condition has guiding significance for quantitatively evaluating the transformation effect of the hydrocarbon source fluid on the reservoir, optimizing the favorable reservoir and making an exploration and development deployment scheme.
Description
Technical Field
The invention relates to a method for generating a hydrocarbon source fluid corrosion hole-increasing capacity evaluation chart under geological conditions.
Background
The dense oil gas resources in China are rich, industrial breakthrough is realized on the Huhai Bay, songliao, songer and the like, and the dense oil gas geological conditions are realized on a large scale on the Hu Bay, songliao, songer and the like. The wide and stable construction background, large-scale aggregation, close source storage and no long-distance migration are obvious characteristics of compact oil gas. Reservoir porosity is an important site for hydrocarbon occurrence, where secondary erosion is an important way to improve tight reservoir pore penetration performance. Organic matters in the hydrocarbon source rock can release a large amount of organic acids in the hydrocarbon generating process of thermal evolution, and can erode minerals such as feldspar, calcite, clay and the like to form secondary pores with considerable scale, thereby having important effects on improving the reservoir performance and occurrence and aggregation of oil gas. The close proximity characteristics of the tight oil gas source reservoirs determine that similar buried evolution histories exist between the tight oil gas source reservoirs, and organic acids generated along with the acid generation process of the tight oil gas source rocks necessarily have important influence on the close proximity tight reservoirs.
In the aspect of exploring the effects of fluids on reservoir corrosion improvement and the like, different students have carried out a great deal of work, and the technical methods reported in the paper publication are mainly summarized as 2: (1) And (3) carrying out diagenetic effect simulation on the reservoir by using the artificially configured fluid through a diagenetic simulation device, comparing rock mineral change characteristics before and after simulation, and qualitatively analyzing or quantitatively calculating the transformation effect intensity of the fluid on reservoir pore permeation. Because the simulation parameters are limited by experimental conditions, the selection of the simulation parameters is mostly temperature and pressure, the used fluid is mostly single component, and the change rule of the corrosion effect under the action of various geological factors cannot be comprehensively reflected; (2) Based on natural evolution samples with different depths, rock diagenetic effects with different depths are analyzed by using technologies such as sheet identification, scanning electron microscope, electronic probe and the like and a petrology theory, and the rock diagenetic effects are quantitatively analyzed by combining an image statistics technology. Because of the limitation of the number of samples, the conclusion is difficult to comprehensively reflect the diagenetic effect of the whole research area, and the application range is limited.
Patent CN201810116321.6 discloses a quantitative prediction method for corrosion and pore-increasing amount of clastic rock reservoir, which establishes a prediction model of geological parameter-corrosion-porosity under different corrosion effects based on research of clastic rock reservoir sedimentary facies, lithofacies, fluid properties, sedimentary loops, diagenetic stages and fault development conditions, and further can perform prediction evaluation on corrosion pore sizes of clastic rock reservoirs, especially low-pore and low-permeability compact reservoirs.
Patent CN201810116728.9 discloses a quantitative prediction method of feldspar corrosion hole increasing amount, which considers the influence degree of corrosion on feldspar in the hole increasing process, establishes a temperature model and a depth model of feldspar corrosion by researching the diagenetic phase of a target layer in a research area, combines the construction depth, diagenetic phase and fluid environment of the research area and influence factors of feldspar in the corrosion process, establishes a model formula from three aspects of feldspar type, pH value and temperature, determines the dissolution amount of feldspar and the increase and decrease condition of secondary pores, further quantitatively evaluates the hole increasing amount of feldspar corrosion of a clastic rock reservoir, and provides a basis for pore evolution.
The two patents consider the change of part of geological parameters and utilize the important parameter of pH value, wherein the pH value in the method is from the actual measured pH value in the current stratum fluid, and the acid generating capacity of the actual hydrocarbon source rock in different stages is not considered. In addition, the acid discharge efficiency of the hydrocarbon source rock and the opening-closing degree of the corrosion system are not considered, and a certain difference exists between the application result and the actual situation.
Patent CN201811000403.0 provides a quantitative evaluation method for the corrosion degree of feldspar in clastic rock. The quantitative evaluation method comprises the following steps: correcting the feldspar content in the reservoir by using elements with unchanged content of clastic rock in the process of burying the clastic rock into rock, so as to obtain the relative content of the feldspar; drawing a scatter diagram of the relative content and depth of feldspar; performing linear fitting on the scatter diagram to obtain a change curve of the relative content and depth of the feldspar; and (3) obtaining the relative content of the feldspar at a certain depth through a change curve, comparing the relative content of the feldspar at a certain depth with the initial content of the feldspar, and determining the corrosion degree of the feldspar. According to the evaluation method, the theoretical corrosion hole-increasing capability cannot be described on the basis of the chemical reaction hole-increasing mechanism according to the change of the feldspar content in the actual geological section, and the influence of the complex geological condition on the corrosion degree cannot be considered.
The hydrocarbon fluid from the source rock enters the reservoir to react, and the process of changing the reservoir performance is controlled by the acid generating capacity and the acid discharging capacity of the source rock and also under the combined action of factors such as the type of the corrosion reaction mineral, the opening and closing degree of the reaction system and the like. None of the methods disclosed in the above documents achieves the effect of considering the capacity of the hydrocarbon source to erode and increase the pore volume under a variety of geological conditions.
Disclosure of Invention
Aiming at the problems of incomplete consideration of influencing factors, incomplete result application and the like in quantitative evaluation of hydrocarbon source flow on reservoir reconstruction capability in the prior art, the invention provides a method for generating a hydrocarbon source flow corrosion hole-increasing capability evaluation plate under geological conditions by using thermal simulation experimental data and combining a theoretical chemical reaction formula under the condition of fully considering actual influencing factors of organic acid reconstruction of the reservoir.
The first aspect of the invention provides a method for generating a hydrocarbon source fluid corrosion and pore-increasing capability evaluation chart, which comprises the following steps:
s1: analyzing the geological features of the research area to determine a representative well, a hydrocarbon source rock sample or a surrogate thereof, and a reservoir sample or a surrogate thereof;
s2: setting experimental parameters, and carrying out an acid generation experiment of the hydrocarbon source rock;
s3: testing the content of organic acid, and calculating the acid generating capacity of the hydrocarbon source rock;
s4: calculating a theoretical erosion increase Kong Liang;
s5: and (5) changing experimental parameters to obtain corrosion increase Kong Liang under different conditions, and generating corresponding evaluation plates.
According to the invention, in S1, the history of the buried evolution of the representative well can reflect the history of the buried evolution of the investigation horizon of the investigation region.
According to the invention, in S1, the hydrocarbon source rock sample refers to an immature sample (Ro < 0.5%) of the research area, and if the characteristic hydrocarbon source rock sample cannot be obtained, the immature hydrocarbon source rock sample of other areas with the organic matter type consistent with the research area is selected to replace the immature hydrocarbon source rock sample, namely the substitute of the hydrocarbon source rock sample.
According to the invention, in S1, the reservoir rock sample refers to a reservoir rock sample of the research area in the initial stage of diagenetic evolution, no remarkable compressive dissolution, cementation, recrystallization and other secondary rock generation effects occur, and if the characteristic sample cannot be obtained, the characteristic sample can be replaced by a target layer rock core or a fresh outcrop sample, namely a substitute of the reservoir rock sample.
According to some embodiments of the invention, in S1, the geological feature comprises a depositional formation.
According to some embodiments of the invention, S1 further comprises performing X-ray diffraction experimental analysis and TOC content measurement on the determined reservoir sample or surrogate thereof to obtain its mineral composition and TOC content. In the invention, TOC content measurement can be carried out according to national standard of determination of total organic carbon in sedimentary rock (GB/T19145-2003).
According to some embodiments of the invention, in S2, the setting the experimental parameters comprises the steps of:
step A: analyzing the geological parameters of the typical representative well, and recovering the burial history and the thermal evolution history of the research area by using software;
and (B) step (B): determining an experiment starting temperature according to the corresponding relation between the simulation temperature and the expected mirror body reflectivity, and setting a series of experiment simulation temperature points with temperature intervals;
step C: determining burial depths of different depths according to the burial history and the thermal evolution Shi Tu;
step D: according to p=ρgh, determining static rock pressure and formation pressure of each experimental simulation temperature point, wherein g is a gravity constant, and h is the burial depth of different depths; when ρ is the rock density, P is the static rock pressure; when ρ is the water density, P is the formation pressure.
According to some embodiments of the invention, in step a, the geological parameter comprises formation erosion.
According to some embodiments of the invention, in step a, the software used is selected from PetroMod software or other software commonly used in the art.
According to some embodiments of the invention, in step B, the temperature interval is 20-30 ℃, e.g. 25 ℃. According to the invention, previous experiments show that the correlation between the reflectivity (Ro) of the lens body and the simulated temperature is good, and the experimental temperature can be determined according to the relation between the simulated temperature and the Ro in a fitting curve or a fitting formula.
According to some embodiments of the invention, in S2, the source rock sample or substitute thereof is crushed to 40-60 mesh and water (ph=6.5-7.5) is added as a reaction medium before performing the source rock acidogenesis experiment. In the invention, the thermal evolution degree of the hydrocarbon source rock sample or the substitute thereof is low, and the vitrinite reflectance (Ro) is lower than 0.6%.
According to some embodiments of the invention, in S2, a thermal simulation instrument used for performing the hydrocarbon source rock simulated acid production experiment should be capable of realizing synchronous dynamic co-control of temperature, overlying static rock pressure and pore fluid pressure.
According to some embodiments of the invention, in S2, an experiment is performed using a "hydrocarbon source rock formation pore hot-pressing hydrocarbon generation and drainage simulation experiment instrument" (see patent application number CN200810101067.9, publication number CN101520962 a). At the beginning of the simulation experiment, the sample amount and the water addition amount of the hydrocarbon source rock sample used should be recorded.
According to some embodiments of the invention, in S3, the step of testing the organic acid content comprises: after the hydrocarbon source rock acid production experiment is completed, collecting a reaction medium, and carrying out an organic acid content test.
According to some embodiments of the invention, in S3, the reaction medium is stored in a glass container and tested for organic acid content using ion chromatography over 48 hours.
According to some embodiments of the invention, in S3, the organic acid comprises at least one of formic acid, acetic acid, propionic acid, and butyric acid.
According to some embodiments of the invention, in S3, the hydrocarbon source rock acid generating capacity is calculated by formula (1),
Q acid(s) ＝(R Acid(s) ×V Water and its preparation method /m Acid(s) )/(m Sample ×TOC Sample )×10 -6 (1)
Wherein Q is Acid(s) Acid generation amount per unit organic carbon, unit mol/g.toc; r is R Acid(s) The concentration of the organic acid obtained by ion chromatography test is in mg/L; v (V) Water and its preparation method The water adding amount is unit mL for carrying out the hydrocarbon source rock acid generation experiment; m is m Acid(s) Is the average molar mass of the organic acid, and the unit g/mol is the weighted average of the molecular weight of the organic acid; m is m Sample The unit g is the sample quantity of the hydrocarbon source rock for carrying out the acid generation experiment of the hydrocarbon source rock; TOC (total organic carbon) Sample The total organic carbon content in% in the hydrocarbon source rock sample for the hydrocarbon source rock acid generation experiments.
If the hydrocarbon source rock does not contain the vitrinite, the vitrinite reflectivity Ro value representing the maturity parameter cannot be obtained, the solid asphalt reflectivity or other parameters can be tested, and the solid asphalt reflectivity Ro can be converted into the vitrinite reflectivity Ro according to a related formula. When the types and conversion objects of kerogen are different, the conversion plate formulas are different, and the specific conversion method can refer to the paper "Sichuan basin five peaks-Longmaxi group shale maturity research" (DOI: 10.3799/dqkx.2018.125).
According to some embodiments of the invention, in S4, the theoretical erosion increase Kong Liang is calculated by formula (2):
Φ increase the number of ＝(Q Acid(s) ×TOC R ×K TOC ×ρ Hydrocarbon source rock )×K Source store ×E Acid discharge ×(C Degree of openness ×V Opening device +(1-C Degree of openness )×V Closing the door ) X 100% type (2)
Wherein phi is Increase the number of The unit is the theoretical corrosion hole increasing amount; q (Q) Acid(s) Acid generation amount per unit organic carbon, unit mol/g.toc; TOC (total organic carbon) R The unit is the TOC content in the hydrocarbon source rock for actually completing the acid production process; k (K) TOC The TOC recovery coefficient is the ratio of the initial TOC of the low-maturity source rock to the TOC after the acid evolution is completed, and can be calculated according to actual test data or obtained according to a corresponding empirical formula/plate; ρ Hydrocarbon source rock Is the density of the hydrocarbon source rock, and the unit is g/mL; k (K) Source store Is the ratio of the thickness of the hydrocarbon source rock and the reservoir in the geological erosion system; e (E) Acid discharge Acid discharge efficiency of the hydrocarbon source rock is expressed in%, which means that the proportion of the organic acid generated by the hydrocarbon source rock discharged outwards can be determined according to the compaction degree of the hydrocarbon source rock; c (C) Degree of openness The unit of the opening degree of the corrosion system is the degree of outward discharge of corrosion products after the acid reacts with minerals; v (V) Opening device In units of cm, the pore-increasing capability of acid after the acid is completely eroded to a certain mineral in an open system 3 According to the chemical formula of mineral corrosion reactionCalculating to obtain; v (V) Closing the door Is the dissolution of acid to a certain mineral in a closed system, and has pore-increasing capability of other products to be retained, and the unit is cm 3 And/mol, which can be calculated according to the chemical formula of the mineral corrosion reaction.
According to some embodiments of the invention, in S5, the parameter comprises one or more of a source rock maturity, a source reservoir ratio, a source rock acid removal efficiency, and an extent of openness of the erosion system.
According to the invention, the corrosion hole-increasing capability of a specific region due to the change of geological conditions is controlled by the maturity Ro of the hydrocarbon source rock and the source-storage proportion relation K Source store Acid removal efficiency E of hydrocarbon source rock Acid discharge Degree of openness C of the corrosion system Degree of openness Etc. Changes in the corresponding parameters all lead to increases Kong Liang Increase the number of Is a variation of (c). Therefore, according to the actual exploration requirement, the magnitude of the related parameters in S5 can be changed to obtain the increase Kong Liang under different conditions Increase the number of . In the coordinate system, a corresponding evaluation plate is drawn.
A second aspect of the invention provides the use of the method according to the first aspect in the field of oil and gas geological exploration.
According to some embodiments of the invention, parameters such as acid discharge efficiency, source storage proportion, openness degree and the like of a specific region and a horizon can be determined according to related geological data, so that a corrosion and pore-increasing evaluation chart suitable for a hydrocarbon source fluid reservoir in a characteristic research region can be established. The quantitative method is provided for predicting the 'dessert' of the tight reservoir based on characteristics such as geologic body sealing, hydrocarbon source fluid property evolution, source storage configuration and the like.
The invention takes actual geological conditions as constraints, takes thermal simulation experimental data as a basis, combines a theoretical chemical reaction equation, establishes the steps of a calculation method for the corrosion modification effect of the organic acid of the hydrocarbon source rock on the reservoir under the condition of fully considering the actual influence factors of the organic acid modification on the reservoir, and provides a generation method for the evaluation chart of the corrosion hole-increasing capability of the hydrocarbon source fluid under the geological conditions. The method has guiding significance for quantitatively evaluating the reconstruction effect of the hydrocarbon source on the reservoir, preferably favoring the reservoir, and making exploration and development deployment schemes.
Drawings
FIG. 1 is a schematic illustration of the steps for generating a hydrocarbon source fluid erosion and perforation enhancement evaluation template under geological conditions in accordance with the present invention.
FIG. 2 is a graph of evaluation of corrosion and pore-forming ability of hydrocarbon source fluid to a reservoir at various source storage ratios obtained in accordance with example 1 of the present invention.
FIG. 3 is a graph showing evaluation of corrosion and pore-forming ability of hydrocarbon source fluid to a reservoir for different acid-forming efficiencies obtained in example 1 according to the present invention.
FIG. 4 is a graph showing evaluation of corrosion and pore-forming ability of hydrocarbon source fluid to a reservoir at various degrees of openness obtained in accordance with example 1 of the present invention.
FIG. 5 is a graph showing evaluation of corrosion and pore-forming ability of hydrocarbon source fluid to a reservoir at various degrees of openness obtained in accordance with example 1 of the present invention.
Detailed Description
The present invention will be more fully understood by those skilled in the art by the following examples, which are not intended to limit the scope of the present invention in any way.
The invention provides a method for generating a hydrocarbon source fluid corrosion hole-increasing capacity evaluation chart under geological conditions, which specifically comprises the following steps:
step 1, analyzing the geological condition of a region to obtain a sample
Geologic features, such as formation depositions in the investigation region, are analyzed to determine representative well, hydrocarbon source rock samples, and reservoir samples.
Specific: the buried evolution history typically representing the well should reflect the buried evolution history of the studied horizon in the region; the source rock sample should be an immature sample (Ro < 0.5%) of the horizon in the region, if the characteristic source rock sample cannot be obtained, the immature source rock sample in other regions with the organic matter type consistent with the region can be selected to replace the immature source rock sample; the reservoir rock sample is preferably a reservoir rock sample of the horizon in the region at the initial stage of diagenetic evolution, no remarkable compressive dissolution, cementation, recrystallization and other secondary rock generation effects occur, if the characteristic sample cannot be obtained, a target layer core or fresh outcrop sample can be used for replacing the characteristic sample, and an X-ray diffraction experiment is carried out to analyze mineral composition.
Step 2, setting experimental parameters and carrying out hydrocarbon source rock acid production experiments
(1) Setting experimental parameters: and analyzing geological parameters such as stratum erosion and the like of a typical well, and recovering the embedding history and the thermal evolution history of a research area by using petroMod or other software. And determining the initial experiment temperature according to the corresponding relation between the simulation temperature and the expected Ro, and determining a series of simulation experiment temperature points with a certain temperature as an interval, wherein the temperature interval can be 25 ℃. According to the buried history heat Shi Tu, the buried depths of different depths are determined, and according to P=ρgh, the static rock pressure and the formation pressure of each simulated temperature point are determined. Specifically, when ρ is the rock density, P is the static rock pressure; when ρ is the water density, P is the formation pressure.
(2) And (3) carrying out a simulation experiment: before the start of the simulation experiment, the source rock sample was crushed to 40 to 60 mesh and a proper amount of distilled water (ph=7) was added as a reaction medium. The selected thermal simulation instrument can realize synchronous dynamic common control of temperature, overlying static rock pressure and pore fluid pressure. Preferably, a "hydrocarbon source rock stratum pore hot-pressing hydrocarbon generation and discharge simulation experiment instrument" (patent number CN 200810101067.9) is selected for the experiment. At the beginning of the simulation, the amount of sample used and the amount of water added should be recorded.
Step 3, carrying out an organic acid content test to calculate the acid generating capacity of the hydrocarbon source rock
(1) Collecting and testing the organic acid content: and after the hydrocarbon source rock acid production experiment is completed, collecting the simulated water, and testing the organic acid content. Preferably, a glass container is selected for storage and the organic acid content is tested using ion chromatography over 48 hours. The organic acid content test should include primary organic acids such as a, b, c, and d.
(2) Calculating the acid generating capacity of the hydrocarbon source rock: acid generating capacity Q of hydrocarbon source rock Acid(s) Expressed in terms of acid generation amount per unit organic carbon, expressed in terms of mol/g.toc, and calculated as:
Q acid(s) ＝(R Acid(s) ×V Water and its preparation method /m Acid(s) )/(m Sample ×TOC Sample )×10 -6 (1)
Wherein:R acid(s) The concentration of the organic acid obtained by ion chromatography test is in mg/L; v (V) Water and its preparation method Adding water in unit mL for the step 2; m is m Acid(s) Is the average molar mass of the organic acid, and the unit g/mol is the weighted average of the molecular weight of the organic acid; m is m Sample The unit g is the sample quantity of the hydrocarbon source rock in the step 2; TOC (total organic carbon) Sample Is the total organic carbon content in the hydrocarbon source rock sample in step 2, expressed in%.
Step 4. Calculating theoretical erosion increase Kong Liang
The easily erodable minerals such as feldspar, calcite and the like can erode under the action of acidic substances to generate new minerals. The theoretical corrosion pore-increasing amount is related to the actual acid generating capacity of the hydrocarbon source rock, the source-storage combination proportion, the system opening degree, the corrosion mineral type and the like, and the specific calculation formula is as follows:
Φ increase the number of ＝(Q Acid(s) ×TOC R ×K TOC ×ρ Hydrocarbon source rock )×K Source store ×E Acid discharge ×(C Degree of openness ×V Opening device +(1-C Degree of openness )×V Closing the door ) X 100% type (2)
In phi, phi Increase the number of The unit is the theoretical corrosion hole increasing amount; q (Q) Acid(s) The unit mol/g.toc of the organic carbon acid generating capacity of the hydrocarbon source rock calculated in the step 3; TOC (total organic carbon) R The unit is the TOC content in the hydrocarbon source rock for actually completing the acid production process; k (K) TOC The TOC recovery coefficient is the ratio of the initial TOC of the low-maturity source rock to the TOC after the acid evolution is completed, and can be calculated according to actual test data or obtained according to a corresponding empirical formula/plate; ρ Hydrocarbon source rock Is the density of the hydrocarbon source rock, and the unit is g/mL; k (K) Source store Is the ratio of the thickness of the hydrocarbon source rock and the reservoir in the geological erosion system; e (E) Acid discharge Acid discharge efficiency of the hydrocarbon source rock is expressed in%, which means that the proportion of the organic acid generated by the hydrocarbon source rock discharged outwards can be determined according to the compaction degree of the hydrocarbon source rock; c (C) Degree of openness The degree of openness of the corrosion system is expressed as% and indicates the degree of outward discharge of corrosion products after the acid reacts with the minerals. V (V) Opening device In units of cm, the pore-increasing capability of acid after the acid is completely eroded to a certain mineral in an open system 3 According to mineral corrosion reactionCalculating a chemical formula; v (V) Closing the door Is the dissolution of acid to a certain mineral in a closed system, and has pore-increasing capability of other products to be retained, and the unit is cm 3 And/mol, which can be calculated according to the chemical formula of the mineral corrosion reaction.
Step 5, changing experimental parameters to obtain corrosion increase Kong Liang under different conditions, and generating corresponding evaluation patterns
The corrosion hole-increasing capability of a specific region due to the change of geological conditions is controlled by the maturity Ro of the source rock and the source storage proportion relation K Source store Acid removal efficiency E of hydrocarbon source rock Acid discharge Degree of openness C of the corrosion system Degree of openness Etc. Changes in the corresponding parameters all lead to increases Kong Liang Increase the number of Is a variation of (c). Therefore, according to the actual exploration requirement, the magnitude of the relevant parameters in the step 5 can be changed to obtain the increase Kong Liang under different conditions Increase the number of . In the coordinate system, a corresponding evaluation plate is drawn.
Specifically, the present invention is described in detail by the following examples.
Example 1
The extended group of the Erdos basin is widely developed compact oil, which is the main horizon of Chinese compact oil exploration. The hydrocarbon source rock is mainly distributed in a long 7 section, and the organic matter type of the hydrocarbon source rock is II 1 The reservoir rock is widely contacted with the long 7 sections and is closely adjacent to the long 7 sections.
In the embodiment of the invention, a method for generating an evaluation chart of the reconstruction capability of a hydrocarbon source rock fluid of an extended group in a south of Erdos on a feldspar sandstone reservoir is provided, and as shown in a figure 1, the method comprises the following steps:
step 101, analyzing the geological condition of the region to obtain a sample
Geologic features, such as formation depositions in the investigation region, are analyzed to determine representative well, hydrocarbon source rock samples, and reservoir samples.
The research area is located in the south of the Hudoos, and the X well is a compact oil exploration well in the area and can reflect the structural deposition characteristics of the horizon in the area. The long 7-section hydrocarbon source rock sample is II 1 The average heat evolution degree Ro of the prior hydrocarbon source rock is 0.86 percent, and the TOC content is 4.9 percent. Not found in the areaLow maturity (Ro<0.5 percent of hydrocarbon source rock sample, so that the organic matter type is selected as II 1 Type oil shale sample having a TOC content of 17.8% and a maturity ro=0.35%. The reservoir rock sample in the area is mainly made of fine sand sandstone, a core sample is collected, and an X-diffraction full-rock mineral content test is carried out, so that the result shows that the maximum quartz content in the extended group sandstone reservoir is 56.6%, the secondary feldspar is 26.1%, and the clay and calcite are 11.0% and 1.9% respectively.
Step 2, setting experimental parameters and carrying out hydrocarbon source rock acid production experiments
(1) Setting experimental parameters: the experimental parameters are set according to the burial evolution Shi Tu of the 79 well of the red river, the specific steps can be referred to in patent CN200810101067.9, the set experimental key parameters are listed in table 1, and the experimental key parameters are set according to the fitting formula ro= 0.2131e 0.0048T (R 2 = 0.9507) or the fitted curve shown in fig. 2.
TABLE 1 Experimental parameter settings and results for the simulation of the examples
(2) And (3) carrying out a simulation experiment: before each temperature point simulation experiment starts, the hydrocarbon source rock sample is crushed to 40-60 meshes, 200g of the hydrocarbon source rock sample is weighed, and 90mL of distilled water with pH value of 7 is added. The selected thermal simulation instrument can realize synchronous dynamic common control of temperature, overlying static rock pressure and pore fluid pressure. Preferably, an experiment is carried out by selecting a hydrocarbon source rock stratum pore hot-pressing hydrocarbon generation and discharge simulation experiment instrument (patent number ZL 200810101067.9), wherein the experiment time is set to be 96 hours at constant temperature.
Step 3, carrying out an organic acid content test to calculate the acid generating capacity of the hydrocarbon source rock
(1) Collecting and testing the organic acid content: after each group of simulation experiments is completed, the simulated water is collected by a glass container and filtered to a special sampling tube of an instrument by a disposable 0.45 mu m filter, and the organic acid content is measured. The instrument is Dionex ICS-2100 ion chromatograph, and the anion analysis column is Dionex IonPac TM AS18, specification4X 250mm, anion guard column model Dionex IonPac TM AG18, specification 4X 50mm, anion suppressor Dionex ASRS TM 300 4mm, the eluent is ultrapure water (resistivity 18.2MΩ & cm).
The test results showed that the organic acid content gradually increased with increasing degree of thermal evolution (table 1). The first, second, third and fourth organic acids are the most main four organic acids, and the average content of substances is 15.17%, 65.37%, 11.02% and 8.44%.
(2) Calculating the acid generating capacity of the hydrocarbon source rock: the specific calculation process of the acid generating capacity of the hydrocarbon source rock is described by a YC-1 experiment. In this example, the concentration of the organic acid R obtained by ion chromatography test Acid(s) 1058.64mg/L; water adding quantity V Water and its preparation method 90mL; average molar mass m of organic acid Acid(s) Formic acid molar mass×formic acid molar mass+acetic acid molar mass×acetic acid molar mass+propionic acid molar mass×propionic acid molar mass=46×15.17% +60×65.37% +74×11.02% +88×8.44% = 61.78g/mol; the consumption m of the hydrocarbon source rock sample Sample =200g; TOC of simulation sample Sample =17.8%. Substituting the parameters into formula 1, namely;
Q acid(s) ＝(1058.64×90/67.78)/(200×17.8％)×10 -6 ＝4.33×10 -5 mol/g.toc
Namely, the acid production rate of the extended group hydrocarbon source rock was 4.33X10 under the simulated warm-pressure conditions of the YC-1 series shown in Table 1 - 5 The mol/g.toc, i.e. the extended group of hydrocarbon source rocks at maturity ro=0.72% can produce 4.33×10 per gram of organic carbon -5 A mole of organic acid. Comparing the maturity Ro values of the source rocks under different simulation conditions to obtain the acid production rate of the source rocks in different evolution stages (different maturity) (table 1).
If the hydrocarbon source rock does not contain the vitrinite, the vitrinite reflectivity Ro value representing the maturity parameter cannot be obtained, the solid asphalt reflectivity or other parameters can be tested, and the solid asphalt reflectivity Ro can be converted into the vitrinite reflectivity Ro according to a related formula. When the types and conversion objects of kerogen are different, the conversion plate formulas are different, and the specific conversion method can refer to the paper "Sichuan basin five peaks-Longmaxi group shale maturity research" (DOI: 10.3799/dqkx.2018.125).
Step 4. Calculating theoretical erosion increase Kong Liang
(1) Single mineral theory erosion and porosity calculation
During the process of burying hydrocarbon, the hydrocarbon source rock is accompanied by the generation of organic acid, so that the hydrocarbon source is acidic. The quartz has strong stability in an acidic environment and is not easy to be changed. Feldspar, calcite, clay, etc. are subject to erosion by the action of acids, resulting in a change in reservoir properties. According to the test result in the step 1, the easily etched ore of the sandstone reservoir in the research area is mainly feldspar in an acidic environment, so that the implementation takes the feldspar as an example, and the theoretical corrosion hole increasing amount of the feldspar is calculated.
Potassium feldspar is an important type of feldspar, and the reaction formula of the potassium feldspar and acid is as follows:
2KAlSi 3 O 8 +2CH 3 COOH+7H 2 O→Al 2 Si 2 O 5 (OH) 4 +2K + +4SiO 2
according to the reaction formula, the amount of potassium feldspar eroded is consistent with the consumption of organic acid, namely 1mol of organic acid is needed for 1mol of potassium feldspar to erode, and the generated solid product is clay mineral (Al 2 Si 2 O 5 (OH) 4 ) And quartz (SiO) 2 ). If the corrosion reaction system is completely open (C Degree of openness =100%), i.e. the corrosion products migrate with the fluid out of the reservoir, the potassium feldspar consumes 217.2/2=108.59 cm after complete reaction of 1mol of organic acid 3 I.e. V Opening device ＝108.59cm 3 /mol. If the erosion system is completely blocked (C Degree of openness =0%) then the corrosion product is completely retained inside the reservoir, the volume change rate after corrosion is (217.2-99.2-92.3)/2=12.85 cm 3 Mol/mol, i.e. V Closing the door ＝12.85cm 3 /mol。
(2) Kong Liangji calculation of reservoir theory corrosion increase
The theoretical corrosion pore-increasing amount is related to the actual acid generating capacity of the hydrocarbon source rock, the corrosion mineral type, the combination proportion of the source and the reservoir, the opening degree of the system and the like. The calculation formula of the hole-increasing capability of the source corrosion potassium feldspar of the hydrocarbon source of the Hunan extension group is as follows, and the porosity increment phi is also described by YC-1 series Increase the number of Is calculated according to the following steps:
Φ increase the number of ＝(Q Acid(s) ×TOC R ×K TOC ×ρ Hydrocarbon source rock )×K Source store ×E Acid discharge ×(C Degree of openness ×V Opening device (1-C Degree of openness )×V Closing the door )×100％
In which Q Acid(s) 4.33X10 of the organic carbon acid generating capacity of the hydrocarbon source rock unit calculated in the step 3 -5 mol/g.toc； TOC R The TOC content in the source rock for actually completing the acid generating process, namely the TOC content of the extension group of the current source rock, is 4.9%; k (K) TOC For TOC recovery coefficient, the extended group of hydrocarbon source rocks today have a Ro of 0.86%, according to II 1 Empirical formula K for TOC recovery coefficient of hydrocarbon source rock TOC =0.695×exp (0.732×ro×100) =0.695×exp (0.732×0.86% ×100) =1.30%. Density ρ of hydrocarbon source rock Hydrocarbon source rock ＝2.5g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the The source storage proportion of the Hunan extension group is changed according to the source storage proportion E Acid discharge The calculation process is illustrated by the following example =1:1; the acid removal efficiency of the source rock is related to the processes of hydrocarbon generation, compaction and the like of the source rock, wherein E is taken Acid discharge =60% for the example calculation process; controlled by variation of structural deposition characteristics, there is a difference in the degree of openness of the system, where C is taken Degree of openness =60% for the example calculation process; in the previous step, V has been described by taking potassium feldspar as an example Opening device And V Closing the door The calculated basis and the process of (C) are respectively 108.59cm 3 Per mol and 12.85cm 3 /mol。
Substituting the above parameters into equation 2, namely:
Φ increase the number of ＝(4.33×10 -5 ×4.9％×1.30×2.5)×5×60％×(60％×108.59×(1-60％)×12.85)×100％＝0.1455％
The representative meaning is that under the condition that the source storage ratio is 5:1, the organic acid generated by the hydrocarbon source rock of the extension group ro=0.72% is discharged 60% to enter the reservoir, the organic acid and potassium feldspar are subjected to corrosion, the corrosion product is discharged 60%, and under the condition that the corrosion product is retained by 40%, the porosity of the sandstone is increased by 0.1455%.
Step 5, changing experimental parameters to obtain corrosion increase Kong Liang under different conditions, and generating corresponding evaluation patterns
The corrosion hole-increasing capability of a specific region due to the change of geological conditions is controlled by the maturity Ro of the source rock and the source storage proportion relation K Source store Acid removal efficiency E of hydrocarbon source rock Acid discharge Degree of openness C of the corrosion system Degree of openness Etc. Changes in the corresponding parameters all lead to increases Kong Liang Increase the number of Is a variation of (c). Therefore, according to the actual exploration requirement, the magnitude of the relevant parameters in the step 5 can be changed to obtain the increase Kong Liang under different conditions Increase the number of . In the coordinate system, a corresponding evaluation plate is drawn.
Assuming that the acid removal efficiency of the source rock is 60%, the corrosion system is completely opened, and the source storage proportion is changed, so that the corrosion hole increasing quantity under different maturity Ro is obtained, the maturity Ro is taken as an abscissa, and the corrosion is increased by Kong Liang Increase the number of On the ordinate, a plate for evaluating the corrosion and pore-increasing capacity of hydrocarbon source fluid to a reservoir under different source storage ratios is drawn (fig. 3). Similarly, hydrocarbon source fluid corrosion and pore-increasing capacity evaluation plates (fig. 4) for reservoirs under different acid discharge efficiencies and hydrocarbon source fluid corrosion and pore-increasing capacity plane plates (fig. 5) for reservoirs under different degrees of openness can be drawn.
In the application, parameters such as acid discharge efficiency, source storage proportion, openness degree and the like of a specific region and a layer can be determined according to related geological data, so that a hydrocarbon source fluid reservoir corrosion hole-increasing evaluation chart suitable for a characteristic research region can be established. The quantitative method is provided for predicting the 'dessert' of the tight reservoir based on characteristics such as geologic body sealing, hydrocarbon source fluid property evolution, source storage configuration and the like.
In summary, in the embodiment of the invention, the actual geological conditions in the south jaw area are taken as constraints, the thermal simulation experimental data are taken as the basis, and the calculation method steps of the corrosion modification effect of the hydrocarbon source rock organic acid on the reservoir are established by combining the potassium feldspar corrosion chemical reaction formula under the condition of considering the actual influence factors of the organic acid modification of the reservoir, so that the generation method of the hydrocarbon source corrosion hole-increasing capability evaluation chart under the geological conditions is provided. The method has guiding significance for quantitatively evaluating the reconstruction effect of the hydrocarbon source on the reservoir, preferably favoring the reservoir, and making exploration and development deployment schemes.
It should be noted that the above-described embodiments are only for explaining the present invention and do not limit the present invention in any way. The invention has been described with reference to exemplary embodiments, but rather should be construed as being limited to the words which have been used herein are words of description and illustration, rather than words of limitation. Modifications may be made to the invention as defined within the scope of the appended claims, and the invention may be modified without departing from the spirit and scope of the invention. Although the invention is described herein with reference to particular means, materials and embodiments, the invention is not intended to be limited to the particulars disclosed herein, as the invention extends to all other means and applications which perform the same function.
Claims (12)
1. A method for generating a hydrocarbon source fluid corrosion pore-increasing capability evaluation plate comprises the following steps:
s1: analyzing the geological features of the research area to determine a representative well, a hydrocarbon source rock sample or a surrogate thereof, and a reservoir sample or a surrogate thereof;
s2: setting experimental parameters, and carrying out an acid generation experiment of the hydrocarbon source rock;
s3: testing the content of organic acid, and calculating the acid generating capacity of the hydrocarbon source rock;
s4: calculating a theoretical erosion increase Kong Liang;
s5: changing experimental parameters to obtain corrosion increase Kong Liang under different conditions, and generating corresponding evaluation plates;
s3, calculating the acid generating capacity of the hydrocarbon source rock by the formula (1),
Q acid(s) =（R Acid(s) ×V Water and its preparation method /m Acid(s) ）/（m Sample ×TOC Sample ）×10 -6 (1)
Wherein Q is Acid(s) Acid generation amount per unit organic carbon, unit mol/g.toc;R acid(s) The concentration of the organic acid obtained by ion chromatography test is in mg/L; v (V) Water and its preparation method The water adding amount is unit mL for carrying out the hydrocarbon source rock acid generation experiment; m is m Acid(s) Is the average molar mass of the organic acid, unit g/mol; m is m Sample The unit g is the sample quantity of the hydrocarbon source rock for carrying out the acid generation experiment of the hydrocarbon source rock; TOC (total organic carbon) Sample For the total organic carbon content in units of the hydrocarbon source rock sample for the hydrocarbon source rock acid generation experiments;
in S4, the theoretical erosion increase Kong Liang is calculated by formula (2):
Φ increase the number of =(Q Acid(s) ×TOC R ×K TOC ×ρ Hydrocarbon source rock )×K Source store ×E Acid discharge ×(C Degree of openness ×V Opening device +(1-C Degree of openness )×V Closing the door ) X 100% type (2)
Wherein phi is Increase the number of The unit is the theoretical corrosion hole increasing amount; q (Q) Acid(s) Acid generation amount per unit organic carbon, unit mol/g.toc; TOC (total organic carbon) R The unit is the TOC content in the hydrocarbon source rock for actually completing the acid production process; k (K) TOC Is the TOC recovery coefficient; ρ Hydrocarbon source rock Is the density of the hydrocarbon source rock, and the unit is g/mL; k (K) Source store Is the ratio of the thickness of the hydrocarbon source rock and the reservoir in the geological erosion system; e (E) Acid discharge Acid removal efficiency for source rock, expressed in%; c (C) Degree of openness Is the opening degree of the corrosion system, and is the unit; v (V) Opening device In units of cm, the pore-increasing capability of acid after the acid is completely eroded to a certain mineral in an open system 3 /mol；V Closing the door Is the dissolution of acid to a certain mineral in a closed system, and has pore-increasing capability of other products to be retained, and the unit is cm 3 /mol。
2. The method of claim 1, wherein the geologic feature comprises a depositional structural feature; and/or
S1 further comprises performing X-ray diffraction experimental analysis and TOC content measurement on the determined reservoir sample or surrogate thereof to obtain its mineral composition and TOC content.
3. The method according to claim 1 or 2, wherein in S2, the setting of experimental parameters comprises the steps of:
step A: analyzing the geological parameters of the typical representative well, and recovering the burial history and the thermal evolution history of the research area by using software;
and (B) step (B): determining an experiment starting temperature according to the corresponding relation between the simulation temperature and the expected mirror body reflectivity, and setting a series of experiment simulation temperature points with temperature intervals;
step C: determining burial depths of different depths according to the burial history and the thermal evolution Shi Tu;
step D: according to p=ρgh, determining static rock pressure and formation pressure of each experimental simulation temperature point, wherein g is a gravity constant, and h is the burial depth of different depths; when ρ is the rock density, P is the static rock pressure; when ρ is the water density, P is the formation pressure.
4. A method according to claim 3, wherein in step a, the geological parameter comprises formation erosion; and/or the software used is selected from PetroMod software; and/or
In the step B, the temperature interval is 20-30 ℃.
5. The method of claim 4, wherein in step B, the temperature interval is 25 ℃.
6. The method according to any one of claims 1-2, 4-5, wherein in S2, the source rock sample or a substitute thereof is crushed to 40-60 mesh and water is added as a reaction medium before the source rock acid production experiment is performed.
7. The method according to any one of claims 1-2 and 4-5, wherein a thermal simulation instrument used for carrying out hydrocarbon source rock simulated acid production experiments can realize synchronous dynamic co-control of temperature, overburden static rock pressure and pore fluid pressure.
8. The method according to any one of claims 1-2, 4-5, wherein in S3 the step of testing the organic acid content comprises: after the hydrocarbon source rock acid production experiment is completed, collecting a reaction medium, and carrying out an organic acid content test.
9. The method of claim 8, wherein the reaction medium is stored in a glass container and tested for organic acid content using ion chromatography over 48 hours.
10. The method of claim 9, wherein the organic acid comprises at least one of formic acid, acetic acid, propionic acid, and butyric acid.
11. The method of any one of claims 1-2, 4-5, 9-10, wherein in S5 the parameters include one or more of source rock maturity, source reservoir ratio, source rock acid removal efficiency, and corrosion system openness.
12. Use of the method according to any one of claims 1-11 in the technical field of oil and gas geological exploration.
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