CN114428088A - Method for generating hydrocarbon source fluid corrosion hole-increasing capability evaluation chart - Google Patents
Method for generating hydrocarbon source fluid corrosion hole-increasing capability evaluation chart Download PDFInfo
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Abstract
The invention provides a method for generating a hydrocarbon source fluid corrosion hole-increasing capability evaluation chart, which comprises the following steps: analyzing geological features of the area of interest to determine representative wells, source rock samples or substitutes therefor and reservoir samples or substitutes therefor; setting experiment parameters, and performing a hydrocarbon source rock acidogenesis experiment; testing the content of organic acid, and calculating the acid generating capacity of the hydrocarbon source rock; calculating the theoretical erosion pore-increasing amount; and changing experimental parameters to obtain the erosion and pore-increasing quantity under different conditions, and generating a corresponding evaluation chart. The method for generating the hydrocarbon source fluid corrosion and pore-increasing capability evaluation chart 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 formulating an exploration, development and deployment scheme.
Description
Technical Field
The invention relates to a method for generating a hydrocarbon source fluid corrosion and pore-increasing capability evaluation chart under geological conditions.
Background
China is rich in dense oil and gas resources, industrial breakthroughs are realized in Ordos basins, Sichuan basins and Tarim basins, and Bohai Bay, Songliao, Qusonnel and other basins also have geological conditions for large-scale development of dense oil and gas. The wide, slow and stable construction background, large-scale aggregation, close source storage and no remote migration are remarkable characteristics of compact oil gas. Reservoir porosity is an important site for oil and gas occurrence, wherein secondary erosion is an important way for improving the pore permeability of a compact reservoir. Organic matters in the hydrocarbon source rock release a large amount of organic acid in the process of thermal evolution hydrocarbon generation, minerals such as feldspar, calcite and clay can be corroded, secondary pores with considerable scale are formed, and the method plays an important role in improving the storage performance and gathering oil gas. The characteristics of the close proximity of the compact oil and gas source reservoirs determine that similar buried evolution histories exist among the compact oil and gas source reservoirs, and organic acid generated along with the acid generation process of the compact oil and gas source rock inevitably has important influence on the close proximity of the compact reservoirs.
In the aspect of researching the effects of fluid on reservoir erosion modification and the like, different scholars have carried out a great deal of work, and the technical methods reported in the paper publications are mainly classified into 2 types: (1) and carrying out diagenesis simulation on the reservoir by utilizing the artificially configured fluid through the diagenesis simulation device, comparing rock mineral change characteristics before and after simulation, and qualitatively analyzing or quantitatively calculating the transformation effect strength of the fluid on the reservoir pore seepage. Because of the limitation of experimental conditions, the selection of simulation parameters is mostly temperature and pressure, and the used fluid is mostly a single component and cannot comprehensively reflect the change rule of the erosion action under the action of various geological factors; (2) based on natural evolution samples at different depths, the diagenetic effect of rocks at different depths is analyzed by utilizing technologies such as slice identification, a scanning electron microscope and an electronic probe and by utilizing the petrology theory, and the diagenetic effect strength is quantitatively analyzed by combining with an image statistics technology. Due to the limitation of the number of samples, the conclusion is difficult to fully reflect the diagenetic action of the whole research area, and the application range is limited.
The patent CN201810116321.6 discloses a quantitative prediction method for the corrosion pore volume of a clastic rock reservoir, which is based on the research on the sedimentary facies, the lithofacies, the fluid properties, the sedimentary gyrus, the diagenesis stage and the fault development condition of the clastic rock reservoir, establishes a geological parameter-corrosion effect-porosity prediction model under different corrosion effects, and can further perform prediction evaluation on the size of the corrosion pores of the clastic rock reservoir, especially a low-pore and low-permeability compact reservoir.
The patent CN201810116728.9 discloses a quantitative prediction method for feldspar erosion pore volume, which considers the influence degree of erosion on feldspar in the pore volume increasing process, establishes a temperature model and a depth model of feldspar erosion through lithogenic phase research on a target layer of a research area, establishes a model formula from three aspects of feldspar type, pH value and temperature by combining the structure depth, the diagenetic stage, the fluid environment of the research area and the influence factors of the feldspar in the erosion process, determines the feldspar dissolution volume and the secondary pore volume increase and decrease condition, further quantitatively evaluates the pore volume increase of the clastic rock reservoir feldspar erosion, and provides a basis for pore evolution.
The two patents consider the change of partial geological parameters, utilize the important parameter of pH value, and the pH value in the method is from the actually measured pH value in the current formation fluid, and do not consider the acid generating capacity of the actual hydrocarbon source rock in different stages. In addition, the acid discharge efficiency of the hydrocarbon source rock and the opening-closing degree of the corrosion system are not considered, and the application result is different from the actual situation.
Patent CN201811000403.0 provides a quantitative evaluation method for the degree of feldspar erosion in clastic rock. The quantitative evaluation method comprises the following steps: correcting the content of feldspar in the reservoir through elements with unchanged content of clastic rock in the process of burying the clastic rock into diagenesis to obtain the relative content of the feldspar; drawing a scatter diagram of the relative content and depth of the feldspar; performing linear fitting on the scatter diagram to obtain a change curve of the relative content and the depth of the feldspar; and obtaining the relative content of the feldspar with a certain depth through a variation curve, comparing the relative content of the feldspar with the initial content of the feldspar with a certain depth, and determining the corrosion degree of the feldspar. The evaluation method of the invention cannot explain the theoretical erosion hole-increasing capacity from the chemical reaction hole-increasing mechanism according to the change of feldspar content in the actual geological profile, and cannot consider analyzing the influence of complex geological conditions on the erosion degree.
The hydrocarbon source rock hydrocarbon fluid enters a reservoir to react, and the process of changing the reservoir performance is controlled by the acid discharge capacity of the hydrocarbon source rock acid generating capacity and is under the combined action of the corrosion reaction mineral type, the opening and closing degree of a reaction system and other factors. None of the methods disclosed in the above documents or patents achieve the effect of taking into account the erosive pore-enlarging capacity of the hydrocarbon source fluid under a variety of geological conditions.
Disclosure of Invention
Aiming at the problems of incomplete consideration of influence factors, not wide application of results and the like in quantitative evaluation of hydrocarbon source fluid on reservoir transformation capacity in the prior art, the invention establishes a calculation method step of the corrosion transformation 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 transformed reservoir by using thermal simulation experiment data and combining a theoretical chemical reaction formula, and provides a generation method of a hydrocarbon source fluid corrosion pore-increasing capacity evaluation chart under geological conditions.
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 geological features of the area of interest to determine representative wells, source rock samples or substitutes therefor and reservoir samples or substitutes therefor;
s2: setting experiment parameters, and performing a hydrocarbon source rock acidogenesis experiment;
s3: testing the content of organic acid, and calculating the acid generating capacity of the hydrocarbon source rock;
s4: calculating the theoretical erosion pore-increasing amount;
s5: and changing experimental parameters to obtain the erosion and pore-increasing quantity under different conditions, and generating a corresponding evaluation chart.
According to the invention, in S1, the history of buried evolution of the representative well can reflect the history of buried evolution of the research horizon of the research region.
According to the invention, in S1, the source rock sample refers to an immature sample (Ro < 0.5%) in the research area, and if the characteristic source rock sample cannot be obtained, an immature source rock sample in another area with an organic matter type consistent with that of the research area is selected for substitution, that is, a substitute of the source rock sample.
According to the invention, in S1, the reservoir rock sample refers to a reservoir rock sample in the research area at the initial stage of diagenesis, and no significant secondary diagenesis such as pressure dissolution, cementation, recrystallization and the like occurs, and if the characteristic sample cannot be obtained, the reservoir rock sample can be replaced by a target layer core or a fresh outcrop sample, i.e. a substitute of the reservoir rock sample.
According to some embodiments of the invention, the geological feature comprises a sedimentary formation feature at S1.
According to some embodiments of the invention, S1 further comprises performing X-ray diffraction experimental analysis and TOC content measurement on the identified reservoir sample or surrogate thereof to obtain the mineral composition and TOC content thereof. In the invention, the TOC content can be measured according to the 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 includes the following steps:
step A: analyzing the geologic parameters of the representative well, and recovering the burial history and the thermal evolution history of the research area by using software;
and B: determining an experiment starting temperature according to the corresponding relation between the simulated temperature and the expected vitrinite reflectivity, and setting a series of experiment simulated temperature points with temperature intervals;
and C: determining the burial depths of different depths according to the burial history and the thermal evolution history chart;
step D: determining static rock pressure and formation pressure of each experimental simulation temperature point according to P ═ rho gh, wherein g is a gravity constant, and h is burial depths of different depths; when rho is the rock density, P is the static rock pressure; when ρ is the density of water, P is the formation pressure.
According to some embodiments of the invention, in step a, the geological parameter comprises formation degradation.
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 vitrinite reflectivity (Ro) has good correlation with the simulated temperature, and the experimental temperature can be determined according to the relationship between the simulated temperature and Ro in a fitting curve or a fitting formula.
According to some embodiments of the present invention, in S2, before performing the hydrocarbon source rock acidogenesis experiment, the hydrocarbon source rock sample or the substitute thereof is pulverized to 40-60 mesh, and water (pH 6.5-7.5) is added as a reaction medium. 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 present invention, in S2, the thermal simulation instrument selected for performing the hydrocarbon source rock simulation acid production experiment should be capable of implementing synchronous dynamic co-control of temperature, overburden resting rock pressure, and pore fluid pressure.
According to some embodiments of the present invention, in S2, the experiment is performed by using a "hydrocarbon source rock formation pore thermocompression hydrocarbon production simulation experiment apparatus" (see patent application No. CN200810101067.9, publication No. CN 101520962A). At the beginning of the simulation, the amount of the source rock sample used and the amount of water added should be recorded.
According to some embodiments of the invention, in S3, the step of testing the organic acid content comprises: and after the hydrocarbon source rock acidogenesis experiment is completed, collecting the reaction medium, and carrying out organic acid content test.
According to some embodiments of the present invention, in S3, a glass container is selected for storing the reaction medium, and the organic acid content is tested by ion chromatography within 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 present invention, in S3, the hydrocarbon source rock acidogenic capacity is calculated by formula (1),
Qacid(s)＝(RAcid(s)×VWater (W)/mAcid(s))/(mSample (A)×TOCSample (A))×10-6Formula (1)
Wherein Q isAcid(s)Is the unit organic carbonic acid generating amount and the unit mol/g.toc; rAcid(s)The concentration of the organic acid obtained by ion chromatography test is unit mg/L; vWater (W)The unit of water addition is mL for carrying out the hydrocarbon source rock acidogenesis experiment; m isAcid(s)Is the average molar mass of the organic acid, in g/mol, as a weighted average of the molecular weights of the organic acid; m isSample (A)The unit is the sample amount of the hydrocarbon source rock for carrying out the hydrocarbon source rock acidogenesis experiment, and the unit is g; TOCSample (A)The total organic carbon content in the samples of source rock for the acid production experiments of the source rock was expressed in units%.
It should be noted that if no vitrinite exists in the hydrocarbon source rock, a vitrinite reflectance Ro value representing a maturity parameter cannot be obtained, and the reflectance of the solid asphalt or other parameters in the vitrinite reflectance Ro value can be tested and converted into the vitrinite reflectance Ro according to a related formula. When the kerogen types and conversion objects are different, the conversion chart formula has differences, and a specific conversion method can refer to a paper 'research on the maturity of shale in Wufeng-Longmaxi group in Sichuan basin' (DOI: 10.3799/dqkx.2018.125).
According to some embodiments of the present invention, in S4, the theoretical erosion reaming amount is calculated by equation (2):
Φincrease＝(QAcid(s)×TOCR×KTOC×ρHydrocarbon source rock)×KSource reservoir×EAcid discharge×(CDegree of openness×VOpening device+(1-CDegree of openness)×VClosing device) X 100% formula (2)
Wherein phiIncreaseIn units% for the theoretical erosion pore-increasing amount; qAcid(s)Is the unit organic carbonic acid generating amount and the unit mol/g.toc; TOCRThe TOC content is the unit percent of the TOC content in the hydrocarbon source rock which actually completes the acid production process; kTOCThe TOC recovery coefficient is the ratio of the initial TOC of the low-maturity source rock to the TOC after the acid evolution is finished, and can be obtained by calculation according to actual test data or according to a corresponding empirical formula/chart; rhoHydrocarbon source rockThe density of the hydrocarbon source rock is unit g/mL; kSource reservoirIs the ratio of the thickness of the source rock and the reservoir in the geological erosion system; eAcid dischargeThe acid discharge efficiency of the hydrocarbon source rock is expressed in percent, and the meaning is the proportion of organic acid generated by the hydrocarbon source rock discharged outwards, and can be determined according to the compaction degree of the hydrocarbon source rock; cDegree of opennessThe unit percent is the opening degree of the corrosion system and represents the degree of outward discharge of corrosion products after the acid reacts with minerals; vOpening deviceIs the pore-increasing capacity of unit acid after completely corroding a mineral in an open system, and the unit is cm3The mol can be calculated according to the chemical formula of mineral corrosion reaction; vClosing deviceIs the unit cm of acid which can erode a mineral under a closed system and has the capacity of increasing pores under the retention of other products3And/mol can be calculated according to the chemical formula of the mineral corrosion reaction.
According to some embodiments of the invention, the parameters include one or more of source rock maturity, source reservoir ratio, source rock acid discharge efficiency, and degree of openness of corrosion system in S5.
According to the invention, the corrosion and pore-increasing capacity of a specific area, which is derived from the change of geological conditions, is controlled by the maturity Ro of the hydrocarbon source rock and the source-storage proportional relation KSource reservoirHydrocarbon source rock acid discharge efficiency EAcid dischargeAnd the degree of openness C of the corrosion systemDegree of opennessAnd the like. The change of the corresponding parameters can lead to the increase of the hole diameter phiIncreaseA change in (c). Therefore, according to the actual exploration requirement, the size of the related parameters in the S5 can be changed to obtain the hole increment phi under different conditionsIncrease. And drawing a corresponding evaluation chart in a coordinate system.
A second aspect of the invention provides the use of a method according to the first aspect in the field of oil and gas geological exploration technology.
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 layer can be determined according to related geological data, so that a hydrocarbon source fluid reservoir corrosion pore-increasing evaluation chart suitable for a characteristic research region can be established. A quantitative method is provided for realizing compact reservoir 'dessert' prediction based on characteristics of geologic body closure, hydrocarbon source fluid property evolution, source storage configuration and the like as starting points.
The method is based on thermal simulation experiment data and theoretical chemical reaction equations by taking actual geological conditions as constraints, and under the condition of fully considering actual influence factors of organic acid for modifying a reservoir, the method establishes the steps of the calculation method of the corrosion modification effect of the organic acid of the hydrocarbon source rock on the reservoir, and provides the generation method of the hydrocarbon source fluid corrosion hole-increasing capability evaluation chart under the geological conditions. The method has guiding significance for quantitatively evaluating the transformation effect of the hydrocarbon source fluid on the reservoir, optimizing favorable reservoir and formulating an exploration, development and deployment scheme.
Drawings
FIG. 1 is a schematic diagram of the steps for generating a plate for evaluating the erosive porosity-increasing capability of a hydrocarbon source fluid under geological conditions according to the invention.
Fig. 2 is a chart for evaluating the erosion and pore-increasing capacity of a hydrocarbon source fluid for a reservoir at different source-reservoir ratios according to example 1 of the present invention.
Fig. 3 is a graphical representation of the evaluation of the erosion and pore-growth capacity of a hydrocarbon source fluid in a reservoir at different acid removal efficiencies obtained in example 1 of the present invention.
Fig. 4 is a graphical representation of the evaluation of the erosion and pore-growth capacity of a hydrocarbon source fluid in a reservoir at various openness levels obtained in example 1 of the present invention.
Fig. 5 is a graphical representation of the evaluation of the erosion and pore-growth capacity of a hydrocarbon source fluid in a reservoir at various openness levels obtained in example 1 of the present invention.
Detailed Description
The present invention will be more fully understood by those skilled in the art by describing the present invention in detail with reference to the following examples, which should not be construed as limiting the scope of the present invention in any way.
The invention provides a method for generating a hydrocarbon source fluid corrosion and pore-increasing capability evaluation chart under geological conditions, which specifically comprises the following steps:
Geological features such as tectonic deposits in the area of interest are analyzed to determine representative wells, source rock samples and reservoir samples.
Specifically, the method comprises the following steps: the burial evolution history of a typical representative well should reflect the burial evolution history of the research horizon in the region; the source rock sample is an immature source rock sample (Ro is less than 0.5%) at the position of the area, and if the characteristic source rock sample cannot be obtained, immature source rock samples of other areas with the organic matter type consistent with that of the area can be selected for replacement; the reservoir rock sample is preferably the reservoir rock sample at the position of the area at the initial diagenetic evolution stage, no obvious secondary diagenetic rock actions such as pressure dissolution, cementation, recrystallization and the like occur, if the characteristic sample cannot be obtained, the target layer rock core or a fresh outcrop sample can be used for replacing the characteristic sample, and the analysis mineral composition of the characteristic sample is analyzed through an X-ray diffraction experiment.
Step 2, setting experiment parameters and developing an acid generation experiment of the hydrocarbon source rock
(1) Setting experiment parameters: and analyzing geological parameters such as stratum degradation of a typical well, and recovering the buried history and the thermal evolution history of the research area by using PetroMod or other software. Determining the initial temperature of the experiment according to the corresponding relation between the simulated temperature and the expected Ro, and determining a series of simulated experiment temperature points by taking a certain temperature as an interval, wherein the temperature interval can be 25 ℃. And determining the burial depths of different depths according to the burial history thermal history graph, and determining the static rock pressure and the formation pressure of each simulated temperature point according to the P ═ rhogh. Specifically, when rho is the rock density, P is the static rock pressure; when ρ is the density of water, P is the formation pressure.
(2) Carrying out a simulation experiment: before the simulation experiment begins, a hydrocarbon source rock sample is crushed to 40-60 meshes, and a proper amount of distilled water (pH 7) is added to serve as a reaction medium. The selected thermal simulation instrument can realize synchronous and dynamic co-control of temperature, overlying static rock pressure and pore fluid pressure. Preferably, a hydrocarbon source rock formation pore thermocompression hydrocarbon generation and expulsion simulation experiment instrument (patent number CN200810101067.9) 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 organic acid content test and calculating the acid generating capacity of the hydrocarbon source rock
(1) Collecting and testing organic acid content: and after the hydrocarbon source rock acidogenesis experiment is finished, collecting simulated water, and carrying out organic acid content test. Preferably, glass containers are selected for storage and the organic acid content is tested by ion chromatography over 48 hours. The organic acid content test should include main organic acids such as A, B, C, D, etc.
(2) Calculating the acid generating capacity of the hydrocarbon source rock: acid-generating ability Q of hydrocarbon source rockAcid(s)Expressed in terms of the amount of organic carbon generating acid, in mol/g.toc, the formula is:
Qacid(s)＝(RAcid(s)×VWater (W)/mAcid(s))/(mSample (A)×TOCSample (A))×10-6Formula (1)
Wherein: rAcid(s)The concentration of the organic acid obtained by ion chromatography test is unit mg/L; vWater (W)Adding water in unit mL for step 2; m isAcid(s)Is the average molar mass of the organic acid, in g/mol, as a weighted average of the molecular weights of the organic acid; m isSample (A)The sample amount of the hydrocarbon source rock in the step 2 is unit g; TOCSample (A)Is the total organic carbon content in the source rock sample in step 2, expressed as%.
Step 4, calculating the theoretical erosion pore-increasing amount
Easily-erodible minerals such as feldspar and calcite are eroded under the action of acidic substances to generate new minerals. The theoretical erosion pore-increasing quantity is related to the actual acid production capacity of the hydrocarbon source rock, the source-storage combination proportion, the system openness degree, the type of the erosion minerals and the like, and the specific calculation formula is as follows:
Φincrease＝(QAcid(s)×TOCR×KTOC×ρHydrocarbon source rock)×KSource reservoir×EAcid discharge×(CDegree of openness×VOpening device+(1-CDegree of openness)×VClosing device) X 100% formula (2)
In the formula phiIncreaseIn units% for the theoretical erosion pore-increasing amount; qAcid(s)The organic carbon acid generating capacity of the hydrocarbon source rock unit obtained by calculation in the step 3 is unit mol/g.toc; TOCRTo actually accomplishTOC content in the source rock in the acid production process, unit%; kTOCThe TOC recovery coefficient is the ratio of the initial TOC of the low-maturity source rock to the TOC after the acid evolution is finished, and can be obtained by calculation according to actual test data or according to a corresponding empirical formula/chart; rhoHydrocarbon source rockThe density of the hydrocarbon source rock is unit g/mL; kSource reservoirIs the ratio of the thickness of the source rock and the reservoir in the geological erosion system; eAcid dischargeThe acid discharge efficiency of the hydrocarbon source rock is expressed in percent, and the meaning is the proportion of organic acid generated by the hydrocarbon source rock discharged outwards, and can be determined according to the compaction degree of the hydrocarbon source rock; cDegree of opennessThe degree of openness of the corrosion system is expressed in% and indicates the degree of outward discharge of corrosion products after the reaction of the acid with the mineral. VOpening deviceIs the pore-increasing capacity of unit acid after completely corroding a mineral in an open system, and the unit is cm3The mol can be calculated according to the chemical formula of mineral corrosion reaction; vClosing deviceIs the unit cm of acid which can erode a mineral under a closed system and has the capacity of increasing pores under the retention of other products3And/mol can be calculated according to the chemical formula of the mineral corrosion reaction.
Step 5, changing experimental parameters to obtain erosion pore-increasing amount under different conditions, and generating corresponding evaluation chart
The erosion and pore-increasing capacity of a specific area is controlled by the relationship between the maturity Ro of the source rock and the source-storage proportion K due to the change of geological conditionsSource reservoirHydrocarbon source rock acid discharge efficiency EAcid dischargeAnd the degree of openness C of the corrosion systemDegree of opennessAnd the like. The change of the corresponding parameters can lead to the increase of the hole diameter phiIncreaseA change in (c). Therefore, according to the actual exploration requirement, the size of the related parameters in the step 5 can be changed to obtain the hole increment phi under different conditionsIncrease. And drawing a corresponding evaluation chart in a coordinate system.
Specifically, the present invention is described in detail by the following examples.
Example 1
Extensive development of compact oil by the Erdos basin extended group is the main layer of compact oil exploration in China. The source rocks are mainly distributed in 7 long sections, and the organic matter type of the source rocks is II1Type, store upThe catchment is in wide contact with the long 7 sections and is closely adjacent to the long 7 sections.
In an embodiment of the present invention, a method for generating an evaluation chart of the reformation capacity of extended hydrocarbon source rock fluids in south erdos on feldspar sandstone reservoirs is provided, as shown in fig. 1, the method includes:
Geological features such as tectonic deposits in the area of interest are analyzed to determine representative wells, source rock samples and reservoir samples.
The research area is located in the south Ordos region, and the X well is a compact oil exploration well in the region and can reflect the structural sedimentation characteristics of the layer in the region. The long 7-segment source rock sample is II1The average thermal evolution degree Ro of the type hydrocarbon source rock is 0.86 percent on average at present, and the TOC content is 4.9 percent. No low maturity (Ro) was found in this area<0.5%) of the source rock sample, so that the organic matter type II is selected1The oil shale sample of the type has a TOC content of 17.8% and a maturity Ro of 0.35%. The reservoir rock sample in the region is mainly silty sand sandstone, the core sample is collected, and the X-ray diffraction whole rock mineral content test is carried out, so that the result shows that the quartz content in the prolonged sandstone reservoir is the highest and is 56.6%, the feldspar is 26.1%, and the clay and the calcite are respectively 11.0% and 1.9%.
Step 2, setting experiment parameters and developing an acid generation experiment of the hydrocarbon source rock
(1) Setting experiment parameters: the experimental parameters are set according to the buried evolution history chart of the red river 79 well, the specific steps can refer to patent CN200810101067.9, the set experimental key parameters are listed in table 1, and the fitting formula Ro is 0.2131e0.0048T(R20.9507) or a fitted curve as shown in fig. 2.
TABLE 1 example simulation experiment parameter set-up and results
(2) Carrying out a simulation experiment: before the simulation experiment of each temperature point is started, the source rock sample is crushed to 40-60 meshes, 200g of the source rock sample is weighed, and 90mL of distilled water with the pH value of 7 is added. The selected thermal simulation instrument can realize synchronous and dynamic co-control of temperature, overlying static rock pressure and pore fluid pressure. Preferably, a hydrocarbon source rock formation pore hot-pressing hydrocarbon generation and expulsion simulation experiment instrument (patent number ZL200810101067.9) is selected for carrying out the experiment, and the experiment time is set to be constant temperature time for 96 h.
Step 3, carrying out organic acid content test and calculating the acid generating capacity of the hydrocarbon source rock
(1) Collecting and testing organic acid content: after each group of simulation experiments are completed, the simulated water is collected by a glass container, filtered by a disposable 0.45 mu m filter to a special sample inlet pipe of the instrument, and the content of the organic acid is measured. The instrument model is Dionex ICS-2100 ion chromatograph, and the anion analysis column model is Dionex ion PacTMAS18, size 4X 250mm, anion cartridge type Dionex IonPacTMAG18, size 4X 50mm, anion suppressor Dionex ASRSTM3004 mm, and ultrapure water (resistivity: 18.2 M.OMEGA.. multidot.cm) was used as the rinse liquid.
The test results show that the organic acid content gradually increases with increasing degree of thermal evolution (table 1). The first, second, third and fourth organic acids are the four most important organic acids, and the amount of the substances is 15.17%, 65.37%, 11.02% and 8.44% on average.
(2) Calculating the acid generating capacity of the hydrocarbon source rock: the YC-1 experiment is used for illustrating the specific calculation process of the acid generating capacity of the hydrocarbon source rock. In this example, the organic acid concentration R obtained by ion chromatographyAcid(s)1058.64 mg/L; water addition VWater (W)Is 90 mL; average molar mass m of organic acidsAcid(s)(ii) 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% + 61.78 g/mol; amount m of source rock sampleSample (A)200 g; simulated sample TOCSample (A)17.8%. Substituting the parameters into formula 1, namely;
Qacid(s)＝(1058.64×90/67.78)/(200×17.8％)×10-6＝4.33×10-5mol/g.toc
Namely, the extended hydrocarbon source rock had an acid formation rate of 4.33X 10 under the simulated temperature and pressure conditions of YC-1 series shown in Table 1-5Toc, i.e. the extended hydrocarbon source rock at 0.72% maturity Ro, yields 4.33 × 10 per gram of organic carbon-5mol of organic acid. And (3) comparing the maturity Ro values of the hydrocarbon source rock under different simulation conditions to obtain the acid production rate of the hydrocarbon source rock at different evolution stages (different maturity) (table 1).
It should be noted that if no vitrinite exists in the hydrocarbon source rock, a vitrinite reflectance Ro value representing a maturity parameter cannot be obtained, and the reflectance of the solid asphalt or other parameters in the vitrinite reflectance Ro value can be tested and converted into the vitrinite reflectance Ro according to a related formula. When the kerogen types and conversion objects are different, the conversion chart formula has differences, and a specific conversion method can refer to a paper 'research on the maturity of shale in Wufeng-Longmaxi group in Sichuan basin' (DOI: 10.3799/dqkx.2018.125).
Step 4, calculating the theoretical erosion pore-increasing amount
(1) Calculation of theoretical erosion and porosity of single mineral
During the process of hydrocarbon generation in a buried hydrocarbon source rock, organic acid is generated along with the formation of organic acid, so that the hydrocarbon source fluid becomes acidic. The quartz has strong stability in an acid environment and is not easy to be changed. Feldspar, calcite, clay and the like can generate corrosion under the action of acid, so that the property of a reservoir is changed. According to the test result in the step 1, the sandstone reservoir in the research area is easy to erode in an acid environment, and the ore is mainly feldspar, so the theoretical erosion pore-increasing quantity of the feldspar is calculated by taking the feldspar as an example in the implementation.
Potassium feldspar is an important type of feldspar, and the reaction formula of the reaction of the potassium feldspar and acid is as follows:
2KAlSi3O8+2CH3COOH+7H2O→Al2Si2O5(OH)4+2K++4SiO2
according to the reaction formula, the corrosion amount of the potassium feldspar is consistent with the consumption amount of the organic acid, namely 1mol of the organic acid is needed for corrosion of 1mol of the potassium feldspar, and the generated solid product is clay mineral (Al)2Si2O5(OH)4) And quartz (SiO)2). If the corrosion reaction system is completely open (C)Degree of openness100%), i.e. the corrosion products migrate out of the reservoir with the fluid, the potassium feldspar consumes 217.2/2-108.59 cm after 1mol of organic acid has completely reacted3I.e. VOpening device＝108.59cm3And/mol. If the corrosion system is completely closed (C)Degree of openness0%), the corrosion products are retained in the reservoir completely, and the change rate of the volume after corrosion is (217.2-99.2-92.3)/2-12.85 cm3In mol, i.e. VClosing device＝12.85cm3/mol。
(2) Calculation of theoretical erosion pore-increasing quantity of reservoir
The theoretical erosion pore-increasing amount is related to the actual acid production capacity of the hydrocarbon source rock and the type of the erosion minerals, and is also related to the source storage combination proportion, the system openness degree and the like. The calculation formula of the pore-increasing capacity of the potassium feldspar corroded by the E' nan extended hydrocarbon source fluid is as follows, and the porosity increment phi is also illustrated by YC-1 seriesIncreaseThe calculation process of (2):
Φincrease＝(QAcid(s)×TOCR×KTOC×ρHydrocarbon source rock)×KSource reservoir×EAcid discharge×(CDegree of openness×VOpening device(1-CDegree of openness)×VClosing device)×100％
In the formula, QAcid(s)The organic carbon acid-generating capacity of the hydrocarbon source rock unit calculated in the step 3 is 4.33 multiplied by 10-5mol/g.toc； TOCRThe TOC content of the source rock for actually completing the acid production process, namely the extended group of the current source rock, is 4.9 percent; kTOCExtended group Source rock for TOC recovery coefficient nowadays Ro is 0.86%, according to II1Empirical formula K for TOC recovery coefficient of hydrocarbon source rockTOC0.695 × EXP (0.732 × Ro × 100) ═ 0.695 × EXP (0.732 × 0.86% × 100) ═ 1.30%. Density rho of source rockHydrocarbon source rock＝2.5g/cm3(ii) a The source storage proportion of the Ehan extension group changes and is changed according to the source storage proportion EAcid discharge1:1 is an example to illustrate the calculation process; the acid discharge efficiency of the hydrocarbon source rock is related to the hydrocarbon generation and compaction process of the hydrocarbon source rock, and E is takenAcid dischargeThe calculation process is illustrated as 60%; the degree of system openness is different under the control of the change of the structural deposition characteristics, wherein C is takenDegree of opennessThe calculation process is illustrated as 60%; in the previous step, the potassium feldspar has been taken as an example to illustrate VOpening deviceAnd VClosing deviceThe calculation basis and the process of (1) are respectively 108.59cm3Mol and 12.85cm3/mol。
The above parameters are substituted into formula 2, namely:
Φincrease＝(4.33×10-5×4.9％×1.30×2.5)×5×60％×(60％×108.59×(1-60％)×12.85)×100％＝0.1455％
The significance is that under the condition that the source storage ratio is 5:1, 60% of organic acid generated by the hydrocarbon source rock with the elongation group Ro being 0.72% is discharged into a reservoir, the organic acid is corroded with potassium feldspar, corrosion products are discharged by 60%, and under the condition that the organic acid is retained by 40%, the porosity of the sandstone is increased by 0.1455%.
Step 5, changing experimental parameters to obtain erosion pore-increasing amount under different conditions, and generating corresponding evaluation chart
The erosion and pore-increasing capacity of a specific area is controlled by the relationship between the maturity Ro of the source rock and the source-storage proportion K due to the change of geological conditionsSource reservoirHydrocarbon source rock acid discharge efficiency EAcid dischargeAnd the degree of openness C of the corrosion systemDegree of opennessAnd the like. The change of the corresponding parameters can lead to the increase of the hole diameter phiIncreaseA change in (c). Therefore, according to the actual exploration requirement, the size of the related parameters in the step 5 can be changed to obtain the hole increment phi under different conditionsIncrease. And drawing a corresponding evaluation chart in a coordinate system.
Assuming that the acid discharge efficiency of the hydrocarbon source rock is 60 percent, the corrosion system is completely opened, and the source storage proportion is changed, so that the corrosion pore-increasing quantity under different maturity Ro is obtained, the maturity Ro is taken as the abscissa, and the corrosion pore-increasing quantity phi is taken as the corrosion pore-increasing quantityIncreaseAnd drawing a chart for evaluating the erosion and pore-increasing capacity of the hydrocarbon source fluid to the reservoir under different source-reservoir proportions (figure 3) for the ordinate. Similarly, pairs of hydrocarbon source fluids at different acid removal efficiencies can be mappedA reservoir corrosion pore-increasing capability evaluation chart (figure 4) and a hydrocarbon source fluid corrosion pore-increasing capability plane chart (figure 5) for the reservoir under different openness degrees.
In 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 pore-increasing evaluation chart suitable for a characteristic research area can be established. A quantitative method is provided for realizing compact reservoir 'dessert' prediction based on characteristics of geologic body closure, hydrocarbon source fluid property evolution, source storage configuration and the like as starting points.
In summary, in the embodiment of the invention, the actual geological conditions in the south of the jaw are taken as constraints, the thermal simulation experiment data is taken as a basis, the potassium feldspar corrosion chemical reaction formula is combined, and under the condition that the actual influence factors of the organic acid for modifying the reservoir are considered, the steps of the calculation method for the corrosion modification effect of the organic acid of the hydrocarbon source rock on the reservoir are established, so that the generation method of the hydrocarbon source fluid corrosion pore-increasing capability evaluation chart under the geological conditions is provided. The method has guiding significance for quantitatively evaluating the transformation effect of the hydrocarbon source fluid on the reservoir, optimizing favorable reservoir and formulating an exploration, development and deployment scheme.
It should be noted that the above-mentioned embodiments are only for explaining the present invention, and do not set any limit to the present invention. The invention has been described with reference to an exemplary embodiment, but the words which have been used herein are words of description and illustration, rather than words of limitation. The invention can be modified, as prescribed, within the scope of the appended claims, and changes can be made thereto without departing from the spirit and scope of the invention. Although the invention has been described herein with reference to particular means, materials and embodiments, the invention is not intended to be limited to the particulars disclosed herein, but rather extends to all other methods and applications having the same functionality.
Claims (10)
1. A method for generating a hydrocarbon source fluid corrosion and pore-increasing capability evaluation chart comprises the following steps:
s1: analyzing geological features of the area of interest to determine representative wells, source rock samples or substitutes therefor and reservoir samples or substitutes therefor;
s2: setting experiment parameters, and performing a hydrocarbon source rock acidogenesis experiment;
s3: testing the content of organic acid, and calculating the acid generating capacity of the hydrocarbon source rock;
s4: calculating the theoretical erosion pore-increasing amount;
s5: and changing experimental parameters to obtain the erosion and pore-increasing quantity under different conditions, and generating a corresponding evaluation chart.
2. The method of claim 1, wherein the geological feature comprises a sedimentary formation feature; and/or
S1 further includes performing X-ray diffraction experimental analysis and TOC content measurement on the identified reservoir sample or its surrogate to obtain its mineral composition and TOC content.
3. The method according to claim 1 or 2, wherein in S2, the setting the experimental parameters comprises the following steps:
step A: analyzing the geologic parameters of the representative well, and recovering the burial history and the thermal evolution history of the research area by using software;
and B: determining an experiment starting temperature according to the corresponding relation between the simulated temperature and the expected vitrinite reflectivity, and setting a series of experiment simulated temperature points with temperature intervals;
and C: determining the burial depths of different depths according to the burial history and the thermal evolution history chart;
step D: determining static rock pressure and formation pressure of each experimental simulation temperature point according to P ═ rho gh, wherein g is a gravity constant, and h is burial depths of different depths; when rho is the rock density, P is the static rock pressure; when ρ is the density of water, P is the formation pressure.
4. The method according to any one of claims 1-3, wherein in step A, the geological parameter comprises formation degradation; and/or the software used is selected from PetroMod software; and/or
In step B, the temperature interval is 20-30 deg.C, such as 25 deg.C.
5. The method according to any one of claims 1 to 4, wherein in S2, before conducting the hydrocarbon source rock acidogenesis test, the hydrocarbon source rock sample or the substitute thereof is crushed to 40-60 mesh, and water is added as a reaction medium; preferably, the thermal simulation instrument selected for the hydrocarbon source rock simulation acid production experiment can realize synchronous and dynamic co-control of temperature, overlying static rock pressure and pore fluid pressure.
6. The method according to any one of claims 1 to 5, wherein in S3, the step of testing the content of organic acids comprises: after the hydrocarbon source rock acidogenesis experiment is completed, collecting a reaction medium, and carrying out organic acid content test; preferably, a glass container is selected for storing the reaction medium, and the content of the organic acid is tested within 48 hours by using ion chromatography; more preferably, the organic acid includes at least one of formic acid, acetic acid, propionic acid and butyric acid.
7. The method according to any one of claims 1 to 6, wherein in S3, the acid-generating capacity of the hydrocarbon source rock is calculated by formula (1),
Qacid(s)＝(RAcid(s)×VWater (W)/mAcid(s))/(mSample (A)×TOCSample (A))×10-6Formula (1)
Wherein Q isAcid(s)Is the unit organic carbonic acid generating amount and the unit mol/g.toc; rAcid(s)The concentration of the organic acid obtained by ion chromatography test is unit mg/L; vWater (W)The unit of water addition is mL for carrying out the hydrocarbon source rock acidogenesis experiment; m isAcid(s)Is the average molar mass of the organic acid, in g/mol; m isSample (A)The unit is the sample amount of the hydrocarbon source rock for carrying out the hydrocarbon source rock acidogenesis experiment, and the unit is g; TOCSample (A)The total organic carbon content in the samples of source rock for the acid production experiments of the source rock was expressed in units%.
8. The method according to any one of claims 1 to 7, wherein in S4, the theoretical erosion pore-growth amount is calculated by equation (2):
Φincrease＝(QAcid(s)×TOCR×KTOC×ρHydrocarbon source rock)×KSource reservoir×EAcid discharge×(CDegree of openness×VOpening device+(1-CDegree of openness)×VClosing device) X 100% formula (2)
Wherein phiIncreaseIn units% for the theoretical erosion pore-increasing amount; qAcid(s)Is the unit organic carbonic acid generating amount and the unit mol/g.toc; TOCRThe TOC content is the unit percent of the TOC content in the hydrocarbon source rock which actually completes the acid production process; kTOCRestoring the coefficient for the TOC; rhoHydrocarbon source rockThe density of the hydrocarbon source rock is unit g/mL; kSource reservoirIs the ratio of the thickness of the source rock and the reservoir in the geological erosion system; eAcid dischargeIs the hydrocarbon source rock acid removal efficiency, expressed in%; cDegree of opennessThe degree of openness of the corrosion system in units%; vOpening deviceIs the pore-increasing capacity of unit acid after completely corroding a mineral in an open system, and the unit is cm3/mol；VClosing deviceIs the unit cm of acid which can erode a mineral under a closed system and has the capacity of increasing pores under the retention of other products3/mol。
9. The method of any one of claims 1 to 8, wherein the parameters comprise one or more of source rock maturity, source-reservoir ratio, source rock acid discharge efficiency, and degree of openness of corrosion system in S5.
10. Use of the method according to any one of claims 1-9 in the technical field of oil and gas geological exploration.
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