CN114252431A - Method for determining migration path of hydrocarbon-containing hydrothermal fluid in stratum - Google Patents
Method for determining migration path of hydrocarbon-containing hydrothermal fluid in stratum Download PDFInfo
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Abstract
The invention provides a method for determining a migration path of a hydrocarbon-containing hydrothermal fluid in a stratum. The method comprises the following steps: constructing a chemical element tracer indicator based on inorganic elements that are unique in the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process; acquiring the planar distribution of the tracing index values of the target layer chemical elements in the research area; and determining the preferential migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values in the research area. The method can accurately trace the hydrocarbon-containing fluid in the reservoir, is favorable for improving the drilling success rate, saving the exploration investment and finely evaluating the oil and gas reservoir formation favorable area.
Description
Technical Field
The invention belongs to the technical field of formation fluid migration path characterization in the petroleum industry, and particularly relates to a method for determining a formation hydrocarbon-containing hydrothermal fluid migration path based on inorganic elements which are specific in a hydrocarbon source layer and form element exchange with reservoir rock particles when flowing through a reservoir in a hydrocarbon discharging process.
Background
Hydrocarbon-containing hydrothermal fluid tracing is a research hotspot and difficulty of oil and gas geochemistry. The current research methods for the migration direction of the material include a physical simulation experiment method, a numerical simulation method, a three-field coupling analysis method of a temperature field, a stress field and a pressure field, an organic geochemical tracing method and the like. The physical simulation experiment method, the numerical simulation method and the three-field coupling analysis method can only grasp the approximate migration direction; under the influence of 'multi-source multi-stage' mixed effect and secondary change of oil and gas migration of a complex-structured basin, the change of organic geochemical index parameters is disordered, and the organic geochemical record of the oil and gas migration of each stage is difficult to determine.
Disclosure of Invention
In view of the deficiencies of the prior art, it is an object of the present invention to provide a method for efficiently tracking hydrocarbon-containing fluids in a reservoir. The method can accurately trace the hydrocarbon-containing fluid in the reservoir, is favorable for improving the drilling success rate, saving the exploration investment and finely evaluating the oil and gas reservoir formation favorable area.
In order to achieve the above object, the present invention provides a method for determining a migration path of a hydrocarbon-containing hydrothermal fluid in a formation, wherein the method comprises:
constructing a chemical element tracer indicator based on inorganic elements that are unique in the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process;
acquiring the planar distribution of the tracing index values of the target layer chemical elements in the research area;
and determining the preferential migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values in the research area.
In the above method for determining the migration path of a hydrocarbon-containing hydrothermal fluid in a formation, it is preferable that inorganic elements which are specific to the hydrocarbon source layer and form element exchange with the rock particles of the reservoir layer when flowing through the reservoir layer during the hydrocarbon removal are determined by:
acquiring a hydrocarbon source rock sample, a crude oil sample of a target layer and a reservoir rock core sample of a target layer with quartz particles with secondary enlarged edges;
determining the type of the hydrophilic inorganic elements based on the hydrocarbon source rock sample and the crude oil sample; wherein the parent source refers to a parent hydrocarbon source rock;
determining the type of inorganic elements enriched in the secondary enlarged edges of the quartz particles based on the reservoir rock core sample with the secondary enlarged edges of the quartz particles;
based on the kind of the hydrophilic inorganic element and the kind of the inorganic element enriched during secondary enlargement of the quartz particles, selecting the inorganic element which is taken as the hydrophilic inorganic element and the inorganic element enriched during secondary enlargement of the quartz particles, and taking the inorganic element as a specific inorganic element in the hydrocarbon source layer and forming element exchange with rock particles of the reservoir layer when the inorganic element flows through the reservoir layer in the hydrocarbon discharging process;
wherein the reservoir core sample having the quartz particles with the secondary enlarged edges is preferably a rock sample having undergone water-rock interaction; more preferably, the fluid enclosure is filled with fluid; for example, a reservoir core sample with obvious corrosion characteristics and quartz particles with obvious secondary enlarged edges can be selected;
when the reservoir core sample with the quartz particles with the secondary enlarged edge is screened, the reservoir core sample with the quartz particles with the secondary enlarged edge can be screened in a scanning electron microscope test mode, for example, observation is carried out under a microscope by using single polarized light and orthogonal light. The preferable technical scheme realizes that the migration path of the hydrocarbon-containing hydrothermal fluid in the stratum is determined by utilizing the element composition and the change rule of the enlarged edge of the quartz particles in the reservoir.
In one embodiment, determining the type of the hydrophilic inorganic element based on the source rock sample and the crude oil sample comprises:
determining the content of different inorganic elements and the abundance ratio (the abundance ratio refers to the average content of the elements in the geologic body, in particular to the relative share (such as percentage) of the weight of a chemical element in a certain natural body to the total weight of the natural body) of the hydrocarbon source rock sample and the crude oil sample;
determining the type of the hydrophilic inorganic element based on the determination results of the content determination and the abundance ratio of different types of inorganic elements;
wherein determining the content of the different types of inorganic elements in the crude oil sample preferably comprises determining the content of inorganic elements in different group components in the crude oil sample, wherein the group components comprise at least one of aromatic hydrocarbons, non-hydrocarbons and asphaltenes;
wherein, the determination of the content of the different inorganic elements and the determination of the abundance ratio are preferably performed by plasma atomic emission spectrometry, such as ICP-AES test.
In one embodiment, the determining the type of inorganic elements enriched in the secondary enlarged edges of the quartz particles based on the reservoir core sample with the secondary enlarged edges of the quartz particles comprises:
in the reservoir rock core sample with the secondary enlarged edges, defining the quartz particles with the secondary enlarged edges, and detecting different inorganic element contents in the quartz particles and at different positions of the enlarged edges from the particle center to the particle edge;
determining the types of inorganic elements enriched on the secondary enlarged edge of the quartz particles based on the contents of different inorganic elements at different positions from the center of the particles to the edge of the particles;
detecting the contents of different main inorganic elements in the quartz particles and on the enlarged edges from the center of the particles to different positions of the edges of the particles preferably by an electronic probe in-situ detection mode; the detection of the contents of different trace inorganic elements in the quartz particles and at different positions from the center to the edge of the particles on the enlarged side is preferably carried out by in-situ detection with an electron probe in combination with a LA-ICP-MS (laser ablation-plasma mass spectrometer) method.
In one embodiment, the determining the type of inorganic elements enriched in the secondary enlarged edges of the quartz particles based on the reservoir core sample with the secondary enlarged edges of the quartz particles comprises:
preparing the reservoir rock core sample with the quartz particles with the secondary enlarged edges into a sample slice, scanning the sample slice to obtain the plane distribution of the sample slice with different inorganic element contents, and analyzing the enrichment characteristics of different inorganic elements around the quartz particles to determine the types of the inorganic elements enriched with the secondary enlarged edges of the quartz particles;
scanning the sample slices to obtain sample slice plane distribution with different inorganic element contents, preferably by using an XRF (X-ray fluorescence spectrometer); the X-ray fluorescence signals of different inorganic elements in the surface deposits of the thin slice sample are excited, for example, by XRF (X-ray fluorescence spectroscopy) and detected and analyzed, and the X-ray fluorescence signal of an element at a position per unit test time is counted as the content of the element at the position.
In the above method for determining the migration path of hydrothermal hydrocarbon-containing fluid in the formation, preferably, the chemical element tracing index is constructed to characterize the relative content of inorganic elements which are unique in the hydrocarbon source layer and which form element exchanges with reservoir rock particles when flowing through the reservoir during the hydrocarbon drainage process; more preferably, the chemical element tracing indicator is constructed as a ratio of the content of inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during hydrocarbon drainage to the content of inorganic elements that are characteristic of reservoir rock particles and that remain stable in the hot fluid system against migration by the fluid; further preferably, the inorganic elements unique to the hydrocarbon source layer and which form an elemental exchange with reservoir rock particles as they flow through the reservoir during hydrocarbon drainage include at least one of Mn, Fe, and Y; further preferably, the inorganic elements that are characteristic of the reservoir rock particles and remain stable in the hot fluid system against migration by the fluid include Zr and/or Ho; in a specific embodiment, the constructed chemical element tracing index is at least one of Mn/Zr, Y/Ho, MnO/Zr.
In the method for determining the migration path of the formation hydrocarbon-containing hydrothermal fluid, if the constructed chemical element tracing index is the ratio of the content of the inorganic element which is specific in the hydrocarbon source layer and forms element exchange with the reservoir rock particles when flowing through the reservoir during the hydrocarbon discharging process to the content of the inorganic element which is specific in the reservoir rock particles and is stable in the hydrothermal fluid system and is not migrated by the fluid, then the determination of the preferential migration direction of the hydrocarbon-containing fluid can be performed based on the planar distribution of the research region target layer chemical element tracing index values by:
and determining the direction of gradually reducing the chemical element tracing index value as the superior migration direction of the hydrocarbon-containing fluid based on the planar distribution of the chemical element tracing index value of the target layer of the research area.
In the method for determining the migration path of the hydrocarbon-containing hydrothermal fluid in the formation, preferably, the obtaining a planar distribution of target layer chemical element tracer indicator values in the study area includes:
obtaining reservoir rock core samples at different plane positions of a target layer of a research area;
determining chemical element tracing index values of the reservoir core samples at the different plane positions;
determining the plane distribution of the chemical element tracing index values of the target stratum in the research area based on the determined chemical element tracing index values of the reservoir core samples at the different plane positions;
more preferably, determining the chemical element tracing index values of the reservoir core samples at the different plane positions is performed by performing an X-ray diffraction whole-rock analysis on the reservoir core samples at the different plane positions;
further preferably, the X-ray diffraction whole rock analysis is performed using powder samples made from reservoir core samples at different planar positions;
obtaining reservoir core samples at different plane positions of a target layer of a research area by a conventional method, for example, obtaining the reservoir core samples based on the drilled well data of the research area;
wherein the reservoir core samples at different planar locations of the zone of interest may comprise reservoir core samples of typical wells of different hydrocarbon display grades of the zone of interest.
In the method for determining a migration path of a hydrocarbon-containing hydrothermal fluid in a formation, preferably, the determining a planar distribution of a target layer chemical element tracing index value in a study area based on the determined chemical element tracing index values of the reservoir core samples at different planar positions includes:
and compiling a chemical element tracing index value plane distribution contour map of a target layer of the research area based on the determined chemical element tracing index values of the reservoir core samples at different plane positions.
In the method for determining the migration path of the hydrocarbon-containing hydrothermal fluid in the formation, preferably, the method further comprises:
and (3) verifying the preferential migration direction of the hydrocarbon-containing fluid by using reservoir formation period structural characteristics and/or pressure coefficient contour lines and/or oil-gas flow wells and the like.
The inventor finds that when a hydrocarbon-containing fluid passes through a reservoir, the fluid and rock have strong physical and chemical actions, and then minerals and rocks are changed, the actions can reveal the material source, indicate the fluid migration process and strength, and can reflect the action of hydrocarbons in the process. Some inorganic elements that are characteristic of the hydrocarbon source layer and that migrate during the hydrocarbon removal process may chemically react around the rock particles as they flow through the reservoir to form authigenic minerals that are exchanged for elements that may thereby track hydrocarbon-containing fluid transport. Based on the above, the inventor proposes a completely new method for determining the migration path of the hydrocarbon-containing hydrothermal fluid in the formation, which utilizes inorganic elements which are specific in a hydrocarbon source layer and form element exchange with rock particles of the reservoir layer when flowing through the reservoir layer in the hydrocarbon discharging process to construct a chemical element tracing index, and determines the migration path of the hydrocarbon-containing hydrothermal fluid based on the distribution condition of the chemical element tracing index in a work area. The technical scheme provided by the invention can accurately trace the hydrocarbon-containing fluid in the reservoir, and is more favorable for improving the drilling success rate, saving the exploration investment and finely evaluating the oil and gas reservoir favorable area.
Drawings
Fig. 1 is a flowchart of a method for determining a migration path of a hydrocarbon-containing hydrothermal fluid in a formation in example 1.
FIG. 2A is a graph showing the relationship between the trace element content of crude oil and the aromatic hydrocarbon group component in example 1.
FIG. 2B is a graph showing the relationship between the trace element content of crude oil and the non-hydrocarbon group component in example 1.
FIG. 2C is a graph of the trace element content of crude oil versus the non-hydrocarbon + asphaltenes content of the group components in example 1.
FIG. 2D is a graph showing the relationship between the trace element content of crude oil and the asphaltene component of the group in example 1.
FIG. 3A is a graph of the petrographic characteristics of quartz particles at AH2 well 3313.56m under a single polarization microscope in example 1.
FIG. 3B is a cathodoluminescence image of the quartz particles at AH11 well 2824.45m under the microscope in example 1.
FIG. 3C is the rock characterization diagram of the quartz particles at the position of MA18 well 3905.78m under the scanning electron microscope in example 1.
FIG. 4A is a plot of the spot locations used to make electron probe and LA-ICP-MS measurements in example 1.
FIG. 4B is a graph of the in-situ micro-domain elemental content of the quartz particles measured by the electron probe and the LA-ICP-MS at each point in FIG. 4A in example 1.
FIG. 4C is a plot of the spot locations used to make electron probe and LA-ICP-MS measurements in example 1.
FIG. 4D is a graph of the in-situ micro-domain elemental content of the quartz particles measured by the electron probe and the LA-ICP-MS at each point in FIG. 4C in example 1.
FIG. 5A is a full scan XRF elemental Al distribution profile for the sample of flakes from example 1.
Fig. 5B is a full scan XRF elemental Ca distribution profile for the sample of the flakes from example 1.
FIG. 5C is a full scan XRF elemental Fe distribution profile for the sample of flakes from example 1.
FIG. 5D is a full scan XRF elemental K distribution profile for the sample of flakes from example 1.
FIG. 5E is a full scan XRF elemental Mg distribution profile of a sample of the flakes from example 1.
FIG. 5F is a full scan XRF elemental Mn distribution profile for the flake sample of example 1.
FIG. 5G is a full scan XRF elemental Na distribution profile for the sample of flakes from example 1.
FIG. 5H is a full scan XRF elemental Si distribution profile for the sample of flakes from example 1.
FIG. 5I is a full scan XRF elemental Ti distribution profile of a sample of flakes from example 1.
FIG. 6 is a plot of the contour overlay of trace indices MnO/Zr and pressure coefficient for example 1.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be described in detail and completely with reference to the drawings in the embodiments of the present invention. It is to be understood that the embodiments described are only a few embodiments of the present invention, and not all embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
In one embodiment, a method for determining the migration path of a hydrocarbon-containing hydrothermal fluid in a formation comprises:
step S1: constructing a chemical element tracer indicator based on inorganic elements that are unique in the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process;
step S2: acquiring the planar distribution of the tracing index values of the target layer chemical elements in the research area;
step S3: determining the advantageous migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values in the research area;
step S4: and (3) verifying the preferential migration direction of the hydrocarbon-containing fluid by using reservoir formation period structural characteristics and/or pressure coefficient contour lines and/or oil-gas flow wells and the like.
Further, step S1 includes:
step S11: acquiring a hydrocarbon source rock sample, a crude oil sample of a target layer and a reservoir rock core sample of a target layer with quartz particles with secondary enlarged edges;
step S12: determining the types of the hydrophilic inorganic elements based on the hydrocarbon source rock sample and the crude oil sample; wherein, the parent source refers to parent hydrocarbon source rock;
step S13: determining the types of inorganic elements enriched in the secondary enlarged edges of the quartz particles based on the reservoir rock core sample with the quartz particles with the secondary enlarged edges;
step S14: based on the kind of the hydrophilic inorganic element and the kind of the inorganic element enriched while increasing the secondary size of the quartz particles, the inorganic element which is used as the hydrophilic inorganic element and the inorganic element enriched while increasing the secondary size of the quartz particles is selected and used as the specific inorganic element in the hydrocarbon source layer and forms element exchange with the rock particles of the reservoir layer when flowing through the reservoir layer in the hydrocarbon discharging process.
Further, step S12 includes:
step S121: determining the content of different types of inorganic elements and the abundance ratio of a hydrocarbon source rock sample and a crude oil sample;
step S122: and determining the type of the hydrophilic inorganic element based on the determination results of the content of different inorganic elements and the abundance ratio.
Further, step S13 includes:
step S131: in a reservoir rock core sample with quartz particles with secondary enlarged edges, defining the quartz particles with the secondary enlarged edges, and detecting different inorganic element contents in the quartz particles and at different positions of the enlarged edges from the particle center to the particle edge;
step S132: and determining the types of the inorganic elements enriched on the secondary enlarged edge of the quartz particle based on the contents of different inorganic elements at different positions from the center of the particle to the edge of the particle.
Further, step S13 includes:
step S133: preparing a reservoir rock core sample with quartz particles with secondary enlarged edges into a sample slice, scanning the sample slice to obtain the plane distribution of the sample slice with different inorganic element contents, and analyzing the enrichment characteristics of different inorganic elements around the quartz particles to determine the types of the inorganic elements enriched with the quartz particles with secondary enlarged edges.
Further, step S2 includes:
step S21: obtaining reservoir rock core samples at different plane positions of a target layer of a research area;
step S22: determining chemical element tracing index values of the reservoir core samples at different plane positions;
step S23: and determining the plane distribution of the chemical element tracing index values of the target layer in the research area based on the determined chemical element tracing index values of the reservoir core samples at different plane positions.
Further, step S23 includes:
and compiling a chemical element tracing index value plane distribution contour map of a target layer of the research area based on the determined chemical element tracing index values of the reservoir core samples at different plane positions.
Further, the constructed chemical element tracing indicator characterizes the relative content of inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process;
the constructed chemical element tracing indicator is preferably a ratio of the content of inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during hydrocarbon drainage to the content of inorganic elements that are characteristic of the reservoir rock particles and that remain stable in the hot liquid system against fluid migration;
the inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon removal process preferably include at least one of Mn, Fe, and Y; inorganic elements that are characteristic of reservoir rock particles and remain stable in the hot fluid system against migration by fluids preferably include Zr and/or Ho;
for example, the constructed chemical element tracing index is at least one of Mn/Zr and Y/Ho.
Wherein the reservoir core sample with the quartz particles having the secondary enlarged edges is preferably a rock sample which has undergone water-rock interaction; more preferably, the fluid enclosure is filled with fluid; for example, a reservoir core sample may be selected that has significant erosion characteristics and quartz particles with significant secondary upscaled edges.
When the reservoir core sample with the quartz particles with the secondary enlarged edge is screened, the reservoir core sample with the quartz particles with the secondary enlarged edge can be screened in a scanning electron microscope test mode, for example, observation is carried out under a microscope by using single polarized light and orthogonal light.
Wherein determining the content of the different types of inorganic elements in the crude oil sample preferably comprises determining the content of inorganic elements in different group components in the crude oil sample, the group components comprising at least one of aromatic hydrocarbons, non-hydrocarbons and asphaltenes.
The determination of the content of the different inorganic elements and the determination of the abundance ratio are preferably performed by plasma atomic emission spectrometry, such as ICP-AES test.
Detecting the contents of different inorganic elements in the quartz particles and on the enlarged edges from the particle center to different positions of the particle edges preferably by an electronic probe in-situ detection mode; for example, in situ detection using an electron probe in combination with a LA-ICP-MS (laser ablation-plasma mass spectrometer) method.
Wherein, scanning the sample slice to obtain the sample slice plane distribution with different inorganic element contents is preferably carried out by XRF (X-ray fluorescence spectrometer); the X-ray fluorescence signals of different inorganic elements in the surface deposits of the thin slice sample are excited, for example, by XRF (X-ray fluorescence spectroscopy) and detected and analyzed, and the X-ray fluorescence signal of an element at a position per unit test time is counted as the content of the element at the position.
In one embodiment, the chemical element tracing index is constructed as a ratio of the content of inorganic elements which are specific to the hydrocarbon source layer and form element exchange with reservoir rock particles when flowing through the reservoir during hydrocarbon drainage to the content of inorganic elements which are specific to the reservoir rock particles and remain stable in the hot fluid system without being migrated by the fluid, and then, based on the planar distribution of the research region target layer chemical element tracing index values, the determination of the preferential migration direction of the hydrocarbon-containing fluid can be performed by:
and determining the direction of gradually reducing the chemical element tracing index value as the superior migration direction of the hydrocarbon-containing fluid based on the planar distribution of the chemical element tracing index value of the target layer of the research area.
Determining the chemical element tracing index values of the reservoir core samples at different plane positions preferably by carrying out X-ray diffraction whole-rock analysis on the reservoir core samples at different plane positions; performing X-ray diffraction whole-rock analysis is preferably performed using powder samples made from reservoir core samples at different planar locations;
the reservoir core samples at different plane positions of the target layer of the research area are obtained by a conventional method, and the reservoir core samples can be obtained based on the drilled well data of the research area.
The reservoir core samples at different plane positions of the target zone of the research area can comprise reservoir core samples of typical wells of different oil and gas display levels of the target zone of the research area.
Example 1
The embodiment provides a method for determining a migration path of a hydrocarbon-containing hydrothermal fluid in a formation, which is used for judging the direction of the hydrocarbon-containing fluid of a three-cascade baikou spring group in a slope region of a Quercregion Ma lake, as shown in FIG. 1, and specifically comprises the following steps:
step 1: obtaining a sample of a research area; the method specifically comprises the following steps:
acquiring a hydrocarbon source rock sample of a research area, a crude oil sample of a target layer and reservoir core samples at different plane positions of the target layer based on the drilled well data of the research area; preparing the reservoir core sample into a powder sample and a sample slice suitable for detection of a common microscope, a cathode luminescence microscope, a scanning electron microscope electron probe, LA-ICP-MS, XRF and the like;
the reservoir core samples at different plane positions of the target layer of the research area comprise reservoir core samples of typical wells of different oil and gas display levels of the target layer of the research area.
Step 2: determining the types of the parent (source rock) inorganic elements based on the source rock sample and the crude oil sample; the method specifically comprises the following steps:
step 2.1: carrying out plasma atomic emission spectrometry (ICP-AES) on the hydrocarbon source rock sample and the crude oil sample to analyze the content and abundance ratio of different inorganic elements;
wherein, the crude oil sample analyzes the content of inorganic elements in group components of asphaltene, aromatic hydrocarbon, non-hydrocarbon + asphaltene and the like, and the results are shown in figures 2A-2D; the content of inorganic elements in the group component asphaltene is mainly analyzed;
step 2.2: determining the type of the hydrophilic inorganic element based on the determination results of the content determination and the abundance ratio of different types of inorganic elements;
as shown in fig. 2A-2D, the total content of inorganic elements in the crude oil in the example zone is linear with respect to asphaltenes in the crude oil family components, and less correlated with non-hydrocarbons, non-hydrocarbons + asphaltenes, and aromatics, because asphaltenes have higher molecular weights, more complex molecular structures, and greater polarity than non-hydrocarbons; it is easier to provide conditions for the formation of metal complexes, thereby enriching the inorganic elements;
the content of Fe and Mn in the two-fold hydrocarbon source rock stratum is analyzed in an example area, and asphaltene in the crude oil family component of the three-fold oil reservoir is a main carrier of inorganic elements and is characterized by being rich in Mn, Fe and Cr; and (3) combining a hydrocarbon source rock sample and crude oil analysis to determine that main parent elements are Mn, Fe and the like.
And step 3: determining the types of inorganic elements enriched in the secondary enlarged edges of the quartz particles based on the reservoir rock core sample with the quartz particles with the secondary enlarged edges;
observing the rock characteristics of a reservoir rock core sample with quartz particles with secondary enlarged edges under a mirror, and measuring the quartz particles with in-situ micro-areas and slices with two different scales, the main amount of the enlarged edges and the content of trace elements; the method specifically comprises the following steps:
step 3.1: observing the lithology characteristics of quartz particles in the reservoir rock core sample under a microscope by using the sample slice, and screening out the reservoir rock core sample with the quartz particles with secondary enlarged edges;
specifically, the main components (observed by using a sample slice) of the reservoir core sample are observed by using single polarization light and orthogonal light under a microscope, whether the corrosion phenomenon exists or not, whether a quartz enlarged edge exists or not, whether a fluid inclusion is filled or not, and the like are judged; distinguishing quartz enlarged-edge minerals in different phases by utilizing cathodoluminescence observation, and carrying out scanning electron microscope test to analyze the form of secondary quartz particles and the corrosion degree of the edges of the quartz particles; comprehensively judging whether the sample undergoes strong water-rock interaction or not, preferably selecting a reservoir rock core sample with obvious erosion characteristics and quartz enlarged edge characteristics as a reservoir rock core sample with quartz particles with secondary enlarged edges in a target layer of a research area;
as shown in fig. 3A-3C: a reservoir core sample at the position of an AH2 well 3313.56m shows bay-shaped corrosion of quartz particles, clay substitution and rich filling inclusion under a single-polarization microscope; cathode luminescence images of reservoir core samples at AH11 wells 2824.45m show that quartz enlarged edges are obvious; the reservoir core sample at the position of the MA18 well 3905.78m shows that the enlarged edge of quartz and the newly-grown quartz are obvious under a scanning electron microscope; therefore, the sample of the reservoir core in the example area reflects that the migration path of the hydrocarbon fluid has strong fluid-rock interaction, and typical clayization, strong alteration and quartz secondary increase phenomena occur;
step 3.2: in a sample slice of a reservoir rock core sample with quartz particles with secondary enlarged edges, defining the quartz particles with the secondary enlarged edges, and detecting different inorganic element contents in the quartz particles and at different positions of the enlarged edges from the particle center to the particle edge;
selecting a sample slice with obvious secondary enlarged edges, detecting the inner part of quartz particles and the content of main inorganic elements of the enlarged edges in situ by using an electronic probe, and carrying out the detection in the order from the center of the particles to the edge of the particles; considering that the content of trace elements is low, the detection difficulty of in-situ measuring points is high, and the conventional electronic probe means is difficult to realize, the content of the trace inorganic elements in the quartz particles and on the enlarged edges is determined by combining a LA-ICP-MS (laser ablation-plasma mass spectrometer) method, and the detection is also carried out in the order from the particle center to the particle edge;
in the example, the content of easily-migrating elements such as Cr, Co, Ni, Sr, Mn, Fe, Al and the like is measured, the parent (hydrocarbon source rock) type Mn and Fe elements are mainly detected, and a content distribution diagram of the easily-migrating elements is drawn according to the detection result; the results are shown in FIGS. 4A-4D;
step 3.3: determining the types of inorganic elements enriched on the secondary enlarged edge of the quartz particles based on the contents of different inorganic elements at different positions from the center of the particles to the edge of the particles;
as can be seen from fig. 4A-4D, in-situ elemental analysis in the example area shows that from the center (Q-1) of the quartz particle to the enlarged edge (Q-2), secondary enlarged edge enrichment of elements such as Mn, Fe, Al, Co, Ni, Sr, W, etc. appears, indicating that a large amount of inorganic elements in the hydrocarbon-containing hydrothermal fluid passing through the reservoir can react chemically at the periphery of the quartz particle to exchange with the authigenic mineral-forming elements in response to fluid migration;
step 3.4: scanning sample slices of a reservoir rock core sample with quartz particles with secondary enlarged edges to obtain sample slice plane distribution with different inorganic element contents, so as to analyze enrichment characteristics of different inorganic elements around the quartz particles and determine the types of the inorganic elements enriched by the quartz particles with secondary enlarged edges;
specifically, on the basis of a single-point in-situ element, X fluorescence signals of various elements in the surface sediment of a flake-scale sample are excited by XRF (X-ray fluorescence spectrometer) and are detected and analyzed, and the X fluorescence signals of a certain element in unit test time are counted as a measured value of the element; observing enrichment characteristics of the easily-migrated elements around the quartz particles according to continuous element reflection intensity and ratio change obtained by XRF slice scanning; in the example, whether elements such as Fe, Mn, Cr, Sr and the like which are easily influenced by hydrothermal fluid have the phenomenon of aggregation around quartz particles is observed, and the characteristics that the enlarged edge of the quartz particles is influenced by the hydrocarbon-containing hydrothermal fluid and the content of the elements is abnormally enriched are further verified from a larger scale; the results are shown in FIGS. 5A-5I;
as can be seen from fig. 5A to 5I, the distribution of elements in the sample flakes exhibited non-uniform characteristics, with significant element aggregation; mn, Fe, Ti and other elements which are easily influenced by the hydrothermal fluid are obviously aggregated or filled around quartz particles, and the phenomenon that the elements form abnormally high element content points at the edges of the particles under the influence of the hydrothermal fluid is shown;
from the results of the above step 3.1 to step 3.4, the types of the inorganic elements enriched in the secondary growth edge of the quartz particle include Mn, Fe, and the like.
And 4, step 4: determining inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process;
specifically, the method comprises the following steps: based on the kind of the hydrophilic inorganic element and the kind of the inorganic element enriched while increasing the secondary size of the quartz particles, the inorganic element which is used as the hydrophilic inorganic element and the inorganic element enriched while increasing the secondary size of the quartz particles is selected and used as the specific inorganic element in the hydrocarbon source layer and forms element exchange with the rock particles of the reservoir layer when flowing through the reservoir layer in the hydrocarbon discharging process.
And 5: constructing a chemical element tracer indicator based on inorganic elements that are unique in the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process;
the constructed chemical element tracing indicator characterizes the relative content of inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles when flowing through the reservoir during hydrocarbon drainage, in particular MnO/Zr, where Mn is a chemical element tracing indicator characterizes inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles when flowing through the reservoir during hydrocarbon drainage, Zr is an element that is very chemically inert, inorganic elements that generally remain stable in hydrothermal systems and are not readily displaced by fluids.
Step 6: acquiring the planar distribution of the tracing index values of the target layer chemical elements in the research area; the method specifically comprises the following steps:
step 6.1: determining chemical element tracing index values of the reservoir core samples at different plane positions;
specifically, respectively carrying out X-ray diffraction full-rock analysis (XRD) on powder samples of reservoir core samples at different plane positions of a target layer in a research area to obtain a chemical element tracing index MnO/Zr value of each reservoir core sample;
step 6.2: and drawing up a plane distribution contour map (as shown in figure 6) of the chemical element tracing index MnO/Zr value of the target layer of the research area based on the determined chemical element tracing index MnO/Zr values of the reservoir core samples at different plane positions.
And 7: determining the advantageous migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values in the research area;
specifically, determining a direction of gradually reducing the index value of the chemical element tracing as a preferential migration direction of the hydrocarbon-containing fluid; the results are shown in FIG. 6; as can be seen from FIG. 6, the preferable trace indicator MnO/Zr in the example zone decreases gradually from the high-value zone of the Ma18 and Da10 wells to the north, west and east slopes (red arrows indicate the dominant path).
And 8: verifying the preferential migration direction of the hydrocarbon-containing fluid by using the reservoir formation period structural characteristics, the oil-gas flow well and the pressure coefficient;
the pressure coefficient contour is shown in FIG. 6; and 7, the determined predominant migration direction of the hydrocarbon-containing fluid is completely consistent with the known reservoir formation period structure and the oil-gas flow well, and has higher consistency with the pressure coefficient contour line.
In the above embodiment, the inventor utilizes the most widely distributed and highest-content quartz minerals in the land-source clastic rock to analyze the next generation of element characteristics with different scales such as large-edge in-situ micro-regions, thin slices, whole rocks and the like, constructs a parent (hydrocarbon source rock) element index, establishes the relationship between element content change and migration distance, and forms a new method for tracing the migration of hydrocarbon-containing fluids by using self-generated quartz inorganic elements.
In the embodiment, the method for determining the migration path of the formation hydrocarbon-containing hydrothermal fluid provided by the invention is applied to the determination of the hydrocarbon-containing fluid direction of the three-cascade baikou spring group in the Quercolor basin Mar lake slope region; the migration direction of the hydrocarbon-containing fluid can be effectively traced based on the composition and content change of the authigenic quartz element, and Mn/Zr, Y/Ho and the like are constructed as effective element indexes for indicating a migration and aggregation path; the method is used for carrying out fine tracing on the superior migration and convergence paths and directions of the hydrocarbon-containing fluid in east and west slope regions of the depression of the Ma lake, effectively guiding exploration production, mainly guiding fine evaluation and target deployment of far source oil and gas reservoir regions outside the source of the east slope region, combining the studies of reservoir period construction, reservoir layer distribution and the like, and newly realizing near hundred million-ton-scale reserves. The practical feasibility of the technical scheme provided by the invention is verified, and the popularization and application prospects are realized.
The principle and the implementation mode of the invention are explained by applying specific embodiments in the invention, and the description of the embodiments is only used for helping to understand the method and the core idea of the invention; meanwhile, for a person skilled in the art, according to the idea of the present invention, there may be variations in the specific embodiments and the application scope, and in summary, the content of the present specification should not be construed as a limitation to the present invention.
Claims (18)
1. A method for determining the migration path of hydrocarbon-containing hydrothermal fluid in a stratum, wherein the method comprises the following steps:
constructing a chemical element tracer indicator based on inorganic elements that are unique in the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process;
acquiring the planar distribution of the tracing index values of the target layer chemical elements in the research area;
and determining the preferential migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values in the research area.
2. The determination method as defined in claim 1, wherein the inorganic elements that are characteristic of the hydrocarbon source layer and that form an elemental exchange with reservoir rock particles as they flow through the reservoir during the hydrocarbon drainage process are determined by:
acquiring a hydrocarbon source rock sample, a crude oil sample of a target layer and a reservoir rock core sample of a target layer with quartz particles with secondary enlarged edges;
determining the type of the hydrophilic inorganic elements based on the hydrocarbon source rock sample and the crude oil sample; wherein the parent source refers to a parent hydrocarbon source rock;
determining the type of inorganic elements enriched in the secondary enlarged edges of the quartz particles based on the reservoir rock core sample with the secondary enlarged edges of the quartz particles;
based on the kind of the hydrophilic inorganic element and the kind of the inorganic element enriched during secondary enlargement of the quartz particles, the inorganic element which is taken as the hydrophilic inorganic element and the inorganic element enriched during secondary enlargement of the quartz particles is selected and taken as the inorganic element which is specific in the hydrocarbon source layer and forms element exchange with the rock particles of the reservoir layer when flowing through the reservoir layer in the hydrocarbon discharging process.
3. The determination method according to claim 2, wherein the reservoir core sample in which the quartz particles with secondary enlarged edges are present is a rock sample that has undergone water-rock interaction;
preferably, the reservoir core sample with the secondary enlarged edges of the quartz particles is provided with erosion characteristics and/or filled with fluid inclusions.
4. The determination method of claim 2, wherein determining the species of the parent inorganic element based on the source rock sample and the crude oil sample comprises:
determining the content of different inorganic elements and the abundance ratio of the hydrocarbon source rock sample and the crude oil sample;
and determining the type of the hydrophilic inorganic element based on the determination results of the content of different inorganic elements and the abundance ratio.
5. The method of determining as defined in claim 4, wherein performing heterogeneous inorganic element content determinations on the crude oil sample comprises determining the content of inorganic elements in different families of components in the crude oil sample, the families of components including at least one of aromatic hydrocarbons, non-hydrocarbons, and asphaltenes.
6. The determination method according to claim 4, wherein the performing the determination of the content of the different kinds of inorganic elements and the determination of the abundance ratio are performed using plasma atomic emission spectrometry.
7. The determination method according to claim 2, wherein determining the type of inorganic elements enriched in the secondary enlarged quartz particles based on the reservoir core sample with the secondary enlarged quartz particles comprises:
in the reservoir rock core sample with the secondary enlarged edges, defining the quartz particles with the secondary enlarged edges, and detecting different inorganic element contents in the quartz particles and at different positions of the enlarged edges from the particle center to the particle edge;
and determining the types of the inorganic elements enriched on the secondary enlarged edge of the quartz particle based on the contents of different inorganic elements at different positions from the center of the particle to the edge of the particle.
8. The determination method according to claim 7,
detecting the content of main inorganic elements in different inorganic elements in the quartz particles and in different positions of the enlarged edge from the particle center to the particle edge by an electron probe in-situ detection mode;
the content of trace inorganic elements in different inorganic elements in the quartz particles and in different positions from the particle center to the particle edge of the enlarged edge is detected by combining the electron probe in-situ detection with a laser ablation-plasma mass spectrometer method.
9. The determination method according to claim 2, wherein determining the type of inorganic elements enriched in the secondary enlarged quartz particles based on the reservoir core sample with the secondary enlarged quartz particles comprises:
and preparing the reservoir rock core sample with the quartz particles with the secondary enlarged edges into a sample slice, and scanning the sample slice to obtain the plane distribution of the sample slices with different inorganic element contents, so as to analyze the enrichment characteristics of different inorganic elements around the quartz particles and determine the types of the inorganic elements enriched with the secondary enlarged edges of the quartz particles.
10. The determination method according to claim 9, wherein scanning the sample slice to obtain sample slice plane distributions of different inorganic element contents is performed by using an X-ray fluorescence spectrometer.
11. The determination method of claim 1, wherein the constructed chemical element tracer indicators characterize the relative content of inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during hydrocarbon drainage;
preferably, the chemical element tracing indicator is constructed as a ratio of the content of inorganic elements that are characteristic of the hydrocarbon source layer and that form an element exchange with reservoir rock particles as they flow through the reservoir during hydrocarbon drainage to the content of inorganic elements that are characteristic of the reservoir rock particles and that remain stable in the hot fluid system against fluid migration.
12. The method of claim 1 or 11, wherein the inorganic elements characteristic of the hydrocarbon source layer and in element exchange with reservoir rock particles as they flow through the reservoir during hydrocarbon drainage comprise at least one of Mn, Fe, and Y.
13. The determination method of claim 11, wherein the inorganic elements that are characteristic of the reservoir rock particles and remain stable in a hot liquid system against migration by fluids comprise Zr and/or Ho.
14. The determination method according to claim 1 or 11, wherein the constructed chemical element tracing index is at least one of Mn/Zr, Y/Ho, MnO/Zr.
15. The determination method according to claim 1, wherein said obtaining a planar distribution of layer chemical element tracer indicator values for the region of interest comprises:
obtaining reservoir rock core samples at different plane positions of a target layer of a research area;
determining chemical element tracing index values of the reservoir core samples at the different plane positions;
and determining the plane distribution of the chemical element tracing index values of the target layer in the research area based on the determined chemical element tracing index values of the reservoir core samples at the different plane positions.
16. The determination method as defined in claim 15, wherein determining the indicator of chemical element tracing values for the reservoir core samples at the different planar positions is performed by performing X-ray diffraction whole-rock analysis on the reservoir core samples at the different planar positions.
17. The determination method according to claim 15, wherein the determining a planar distribution of the chemical element tracing index values of the reservoir core samples at the different planar positions based on the determined chemical element tracing index values of the reservoir core samples at the different planar positions comprises:
and compiling a chemical element tracing index value plane distribution contour map of a target layer of the research area based on the determined chemical element tracing index values of the reservoir core samples at different plane positions.
18. The method of determining of claim 1, wherein the method of determining a migration path for formation hydrocarbon hydrothermal fluid further comprises:
and (3) verifying the preferential migration direction of the hydrocarbon-containing fluid by using reservoir formation period structural characteristics and/or pressure coefficient contour lines and/or oil-gas flow wells and the like.
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