CN114252431B - Method for determining migration path of hydrocarbon-containing hot fluid in stratum - Google Patents
Method for determining migration path of hydrocarbon-containing hot fluid in stratum Download PDFInfo
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Abstract
The invention provides a method for determining a migration path of a hydrocarbon-containing hot fluid in a stratum. The method comprises the following steps: constructing a chemical element trace index based on inorganic elements in the hydrocarbon source layer that are characteristic and form element exchanges with reservoir rock particles as they flow through the reservoir during hydrocarbon removal; acquiring the plane distribution of the trace index values of the target layer chemical elements of the research area; and determining the dominant migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracer index values of the research area. The method can more accurately trace hydrocarbon-containing fluid in the reservoir, and is beneficial to improving the drilling success rate, saving the exploration investment and finely evaluating the favorable region of the oil and gas reservoir.
Description
Technical Field
The invention belongs to the technical field of formation fluid migration path characterization in 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 are exchanged with reservoir rock particles when flowing through the reservoir in a hydrocarbon discharging process.
Background
Hydrocarbon-containing hydrothermal fluid tracers are research hot spots and difficulties in geochemistry of oil and gas. The current research methods about the migration direction comprise a physical simulation experiment method, a numerical simulation method, a temperature field, stress field and pressure field three-field coupling analysis method, 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; the change of the organic geochemical index parameter is disordered by the mixed effect of multiple sources and multiple periods of oil and gas migration of the basin with complex structure and the influence of secondary change, so that the organic geochemical record of the oil and gas migration of each period 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 tracing hydrocarbon-containing fluids in a reservoir. The method can more accurately trace hydrocarbon-containing fluid in the reservoir, and is beneficial to improving the drilling success rate, saving the exploration investment and finely evaluating the favorable region of the oil and gas reservoir.
In order to achieve the above object, the present invention provides a method for determining migration path of hydrocarbon-containing hot fluid in a formation, wherein the method comprises:
constructing a chemical element trace index based on inorganic elements in the hydrocarbon source layer that are characteristic and form element exchanges with reservoir rock particles as they flow through the reservoir during hydrocarbon removal;
acquiring the plane distribution of the trace index values of the target layer chemical elements of the research area;
and determining the dominant migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracer index values of the research area.
In the above-described formation hydrocarbon-containing thermal fluid migration path determination method, preferably, the inorganic element that is unique in the hydrocarbon source layer and that exchanges with the reservoir rock particle-forming element when flowing through the reservoir during hydrocarbon removal is determined by:
acquiring a hydrocarbon source rock sample of a research area, a crude oil sample of a target layer and a reservoir rock core sample of quartz particles with a secondary large edge in the presence of the target layer;
determining the type of the parent inorganic element based on the source rock sample and the crude oil sample; wherein the parent source refers to a parent hydrocarbon source rock;
determining the types of inorganic elements enriched on the secondary large edges of the quartz particles based on the reservoir core samples of the quartz particles with the secondary large edges;
selecting inorganic elements which are used as both the parent inorganic elements and the inorganic elements enriched on the secondary large sides of the quartz particles and are used as inorganic elements which are peculiar 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 based on the types of the parent inorganic elements and the types of the inorganic elements enriched on the secondary large sides of the quartz particles;
wherein the reservoir core sample of quartz particles with secondary large edges is preferably a rock sample that has undergone water-rock interactions; more preferably having erosion features and/or being filled with fluid inclusions; for example, a reservoir core sample may be selected that has significant erosion characteristics and has significant secondary large edges of quartz particles;
the method can be used for screening the reservoir rock core samples with the quartz particles with the secondary large edges by adopting a scanning electron microscope test mode, for example, observing under a microscope by using single polarized light and orthogonal light. The optimized technical scheme realizes the determination of the migration path of the hydrocarbon-containing hot fluid in the stratum by utilizing the element composition and the change rule of the enlarged edge of the quartz particles in the reservoir.
In a specific embodiment, determining the type of the parent inorganic element based on the source rock sample and the crude oil sample comprises:
determining the content of different kinds of inorganic elements and the abundance ratio (the abundance ratio refers to the average content of the elements in the geologic body, and concretely refers to the relative share (such as percentage) of the weight of one 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;
based on the determination results of the content determination and the abundance ratio of different types of inorganic elements, the type of the parent inorganic element is determined;
wherein the determination of the content of different kinds of inorganic elements in the crude oil sample preferably comprises determining the content of inorganic elements in different family components in the crude oil sample, the family components comprising at least one of aromatic hydrocarbons, non-hydrocarbons and asphaltenes;
wherein, the determination of the content of the inorganic elements of different types and the determination of the abundance ratio are preferably performed by adopting a plasma atomic emission spectrometry, such as an ICP-AES test.
In one embodiment, determining the type of inorganic element enriched in the secondary large edges of the quartz particles based on the reservoir core sample of the quartz particles with the secondary large edges comprises:
in the reservoir rock core sample with the quartz particles with the secondary large edges, the quartz particles with the secondary large edges are defined, and the content of different inorganic elements in the quartz particles and at different positions from the center of the particles to the edges of the particles is detected;
determining the types of inorganic elements enriched on the secondary large sides of the quartz particles based on the contents of different inorganic elements at different positions from the center of the particles to the edges of the particles;
the method is characterized in that the detection of the content of inorganic elements with different main amounts in the quartz particles and at different positions from the center of the particles to the edge of the particles on the enlarged side is preferably performed by an electronic probe in-situ detection mode; the detection of the content of different trace inorganic elements in the interior of the quartz particles and at different positions from the center of the particles to the edges of the particles on the enlarged sides is preferably carried out by an electronic probe in situ detection combined with a LA-ICP-MS (laser ablation-plasma mass spectrometer) method.
In one embodiment, determining the type of inorganic element enriched in the secondary large edges of the quartz particles based on the reservoir core sample of the quartz particles with the secondary large edges comprises:
preparing a sample slice from the reservoir rock core sample with the quartz particles with the secondary large edges, and scanning the sample slice to obtain sample slice plane distribution with different inorganic element contents, so as to analyze the enrichment characteristics of different inorganic elements around the quartz particles to determine the types of the inorganic elements enriched by the secondary large edges of the quartz particles;
scanning the sample slice to obtain sample slice plane distribution with different inorganic element contents, wherein the sample slice plane distribution is preferably performed by using an XRF (X-ray fluorescence spectrometer); for example, XRF (X-ray fluorescence spectrometer) is used to excite the X-fluorescence signals of different inorganic elements in the surface sediment of the sheet sample, and detection analysis is performed, and the X-fluorescence signal count of a certain element in a unit test time at a certain position is used as the content of the element at the position.
In the above method for determining migration paths of hydrocarbon-containing thermal fluid in a formation, preferably, the chemical element trace index obtained by construction represents the relative content of inorganic elements which are specific in the hydrocarbon source layer and which are exchanged with rock particles forming elements of the reservoir layer when flowing through the reservoir layer in the hydrocarbon removal process; more preferably, the chemical element trace index is constructed as the ratio of the content of inorganic elements that are characteristic in the hydrocarbon source layer and that form element exchanges with the reservoir rock particles when flowing through the reservoir during hydrocarbon removal to the content of inorganic elements that are characteristic in the reservoir rock particles and that remain stable in the hot liquid system from fluid migration; further preferably, the inorganic elements in the hydrocarbon source layer that are specific and that are exchanged with reservoir rock particles forming elements when flowing through the reservoir during hydrocarbon removal include at least one of Mn, fe, and Y; further preferably, the inorganic elements in the reservoir rock particles that are characteristic and remain stable in the hot liquid system from fluid migration include Zr and/or Ho; in a specific embodiment, the chemical element tracing index obtained by construction is at least one of Mn/Zr, Y/Ho and MnO/Zr.
In the above-mentioned method for determining migration path of hydrocarbon-containing thermal fluid in stratum, if the chemical element tracing index obtained by construction is the ratio of the content of inorganic elements which are peculiar to hydrocarbon source layer and are exchanged with reservoir rock particles forming elements when flowing through reservoir during hydrocarbon discharge to the content of inorganic elements which are peculiar to reservoir rock particles and remain stable in thermal fluid system and are not migrated by fluid, at this time, based on the planar distribution of chemical element tracing index values in target layer in research area, the dominant migration direction of hydrocarbon-containing fluid can be determined by:
and determining the direction in which the chemical element tracing index value gradually decreases as the dominant migration direction of the hydrocarbon-containing fluid based on the layer chemical element tracing index value plane distribution of the research area.
In the above method for determining a migration path of a hydrocarbon-containing thermal fluid in a formation, preferably, the obtaining a planar distribution of trace index values of chemical elements in a target layer in a research area includes:
obtaining reservoir rock core samples at different plane positions of a target layer of a research area;
determining chemical element tracer index values of reservoir core samples at the different planar locations;
determining the target layer chemical element tracing index value plane distribution of the research area based on the determined chemical element tracing index values of the reservoir rock 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 full rock analysis mode on the reservoir core samples at the different plane positions;
further preferably, the X-ray diffraction full rock analysis is performed using powder samples made of reservoir core samples at different planar locations;
the method comprises the steps that a reservoir rock core sample at different plane positions of a target layer of a research area is obtained by a conventional method, and the reservoir rock core sample can be obtained based on drilling 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 above method for determining a migration path of a hydrocarbon-containing thermal fluid in a formation, preferably, the determining, based on the determined chemical element tracing index values of the reservoir core samples at the different plane positions, a plane distribution of the chemical element tracing index values of the target layer in the research area includes:
and compiling a chemical element tracing index value plane distribution contour map of the target layer of the research area based on the determined chemical element tracing index values of the reservoir rock core samples at different plane positions.
In the above method for determining a migration path of a hydrocarbon-containing hot fluid in a formation, the method preferably further comprises:
and verifying the dominant migration direction of the hydrocarbon-containing fluid by using the reservoir formation characteristics and/or the pressure coefficient contour lines and/or the oil-gas flow wells and the like.
The inventor finds that when hydrocarbon-containing fluid passes through a reservoir, the fluid and rock undergo strong physical and chemical actions, so that minerals and rocks are changed, and the actions can reveal substance sources, indicate fluid migration processes and strengths, and reflect the actions of hydrocarbons in the processes. Some inorganic elements that are characteristic of hydrocarbon sources and that are mobile during hydrocarbon removal can react chemically at the periphery of the rock particles as they flow through the reservoir to form autogenous minerals that form elemental exchanges, whereby hydrocarbon-containing fluid transport can be tracked. Based on the above, the inventor provides a brand new method for determining the migration path of the hydrocarbon-containing hot fluid in the stratum, which constructs a chemical element tracing index by utilizing inorganic elements which are specific in a hydrocarbon source layer and are exchanged with rock particles forming elements in the reservoir layer when the hydrocarbon is discharged and flows through the reservoir layer, and determines the migration path of the hydrocarbon-containing hot 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 hydrocarbon-containing fluid in the reservoir, and is more beneficial to improving the drilling success rate, saving the exploration investment and finely evaluating the favorable region of the oil and gas reservoir.
Drawings
FIG. 1 is a flow chart of a method for determining migration paths of hydrocarbon-containing hot fluid in a formation according to example 1.
FIG. 2A is a graph showing the relationship between trace element content and aromatic hydrocarbon content in crude oil in example 1.
FIG. 2B is a plot of trace element content versus group component non-hydrocarbon for crude oil in example 1.
FIG. 2C is a plot of crude trace element content versus non-hydrocarbon and asphaltene as a group component in example 1.
FIG. 2D is a plot of crude trace element content versus asphaltene content for the group component in example 1.
FIG. 3A is a graph of the lithology of quartz particles at 3313.56m of AH2 well under a single polarization microscope of example 1.
FIG. 3B is a cathodoluminescence map of the quartz particles at 2824.45m of the AH11 well under the microscope of example 1.
FIG. 3C is a graph of the lithology characteristics of quartz particles at MA18 well 3905.78m under scanning electron microscope in example 1.
FIG. 4A is a plot of the position of the probe used to perform the electronic probe and LA-ICP-MS measurements in example 1.
FIG. 4B is a graph of the in situ micro-region element content of the quartz particles measured by the electron probe and the LA-ICP-MS of each point in FIG. 4A in example 1.
FIG. 4C is a plot of the position of the probe used to perform the electronic probe and LA-ICP-MS measurements in example 1.
FIG. 4D is a graph of in situ micro-region element content of quartz particles measured by the electron probe and the LA-ICP-MS of each point in FIG. 4C in example 1.
FIG. 5A is a graph showing the full scan XRF elemental Al distribution profile of a flake sample of example 1.
FIG. 5B is a graph showing the full-scan XRF elemental Ca distribution profile of a flake sample of example 1.
FIG. 5C is a graph showing the full-sweep XRF elemental Fe distribution profile of a flake sample of example 1.
Fig. 5D is a graph of the full scan XRF elemental K distribution profile of the flake sample of example 1.
FIG. 5E is a graph of the full scan XRF elemental Mg distribution profile of the flake sample of example 1.
FIG. 5F is a graph of the Mn distribution profile of the flake sample of example 1.
Fig. 5G is a graph of the full scan XRF elemental Na profile of the flake sample of example 1.
FIG. 5H is a graph of the full sweep XRF elemental Si distribution profile of the flake sample of example 1.
FIG. 5I is a graph of the full scan XRF elemental Ti profile of the flake sample of example 1.
FIG. 6 is a graph showing the overlay of the trace index MnO/Zr and the contour line of the pressure coefficient in example 1.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention more clear, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings in the embodiments of the present invention. It will be apparent that the described embodiments are some, but not all, embodiments of the invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to fall within the scope of the invention.
In one embodiment, a method of determining a migration path of a hydrocarbon-bearing hot fluid in a formation, the method comprising:
step S1: constructing a chemical element trace index based on inorganic elements in the hydrocarbon source layer that are characteristic and form element exchanges with reservoir rock particles as they flow through the reservoir during hydrocarbon removal;
step S2: acquiring the plane distribution of the trace index values of the target layer chemical elements of the research area;
step S3: determining the dominant migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values of the research area;
step S4: and verifying the dominant migration direction of the hydrocarbon-containing fluid by using the reservoir formation characteristics and/or the pressure coefficient contour lines and/or the oil-gas flow wells and the like.
Further, step S1 includes:
step S11: acquiring a hydrocarbon source rock sample of a research area, a crude oil sample of a target layer and a reservoir rock core sample of quartz particles with a secondary large edge in the presence of the target layer;
step S12: determining the type of the parent inorganic element based on the source rock sample and the crude oil sample; wherein, the parent source refers to a parent hydrocarbon source rock;
step S13: determining the types of inorganic elements enriched on the secondary large sides of the quartz particles based on a reservoir core sample of the quartz particles with the secondary large sides;
step S14: inorganic elements which are used as both the parent inorganic elements and the inorganic elements enriched on the secondary large sides of the quartz particles are selected based on the types of the parent inorganic elements and the types of the inorganic elements enriched on the secondary large sides of the quartz particles, and are used as inorganic elements which are peculiar in a hydrocarbon source layer and are exchanged with 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 inorganic elements and the abundance ratio of a source rock sample and a crude oil sample;
step S122: based on the determination results of the content of the inorganic elements of different types and the abundance ratio, the type of the parent inorganic element is determined.
Further, step S13 includes:
step S131: in a reservoir rock core sample with quartz particles with secondary large edges, delineating the quartz particles with secondary large edges, and detecting different inorganic element contents in the quartz particles and at different positions from the center of the particles to the edges of the particles;
step S132: the type of inorganic element enriched on the secondary large side of the quartz particles is determined based on the content of different inorganic elements at different positions from the center of the particles to the edges of the particles.
Further, step S13 includes:
step S133: and preparing a sample slice from the reservoir rock core sample with the quartz particles with the secondary large edges, and scanning the sample slice to obtain sample slice plane distribution with different inorganic element contents, so as to analyze the enrichment characteristics of different inorganic elements around the quartz particles to determine the types of the inorganic elements enriched by the secondary large edges of the quartz particles.
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 reservoir rock core samples at different plane positions;
step S23: and determining the plane distribution of the target layer chemical element tracing index values of the research area based on the determined chemical element tracing index values of the reservoir rock core samples at different plane positions.
Further, step S23 includes:
and based on the determined chemical element tracing index values of the reservoir rock core samples at different plane positions, compiling a chemical element tracing index value plane distribution contour map of the target layer of the research area.
Further, the constructed chemical element trace index characterizes the relative content of inorganic elements in the hydrocarbon source layer that are specific and that form element exchanges with reservoir rock particles when flowing through the reservoir during hydrocarbon removal;
the chemical element tracing index obtained by construction is preferably the ratio of the content of inorganic elements which are specific in a hydrocarbon source layer and are exchanged with reservoir rock particles forming elements when flowing through the reservoir during hydrocarbon discharge to the content of inorganic elements which are specific in the reservoir rock particles and remain stable in a hot liquid system and are not migrated by fluid;
the inorganic elements in the hydrocarbon source layer that are characteristic and that are exchanged with the reservoir rock particles forming elements when flowing through the reservoir during hydrocarbon removal preferably include at least one of Mn, fe, and Y; inorganic elements that are specific to reservoir rock particles and remain stable in the hot liquid system from fluid migration preferably include Zr and/or Ho;
for example, the chemical element tracing index obtained by construction is at least one of Mn/Zr and Y/Ho.
Wherein a reservoir core sample of quartz particles with secondary large edges is preferably a rock sample that has undergone water-rock interactions; more preferably having erosion features and/or being filled with fluid inclusions; for example, a reservoir core sample may be selected that has significant erosion characteristics and the presence of quartz particles with significant secondary enlarged edges.
The method can be used for screening the reservoir rock core samples with the quartz particles with the secondary large edges by adopting a scanning electron microscope test mode, for example, observing under a microscope by using single polarized light and orthogonal light.
Wherein the determination of the content of different kinds of inorganic elements in the crude oil sample preferably comprises determining the content of inorganic elements in different family components in the crude oil sample, the family components comprising at least one of aromatic hydrocarbons, non-hydrocarbons and asphaltenes.
Among them, the determination of the content of different kinds of inorganic elements and the determination of the abundance ratio are preferably performed by using a plasma atomic emission spectrometry, such as an ICP-AES test.
Wherein, the detection of the content of different inorganic elements in the quartz particles and at different positions from the center of the particles to the edge of the particles on the enlarged side is preferably carried out by an electronic probe in-situ detection mode; for example by means of an electron probe in situ detection combined with LA-ICP-MS (laser ablation-plasma mass spectrometer).
The sample slice is scanned to obtain the planar distribution of the sample slices with different inorganic element contents, and preferably XRF (X-ray fluorescence spectrometer) is adopted; for example, XRF (X-ray fluorescence spectrometer) is used to excite the X-fluorescence signals of different inorganic elements in the surface sediment of the sheet sample, and detection analysis is performed, and the X-fluorescence signal count of a certain element in a unit test time at a certain position is used as the content of the element at the position.
In a specific mode, the chemical element tracing index obtained by construction is the ratio of the content of inorganic elements which are specific to a hydrocarbon source layer and are exchanged with reservoir rock particles when flowing through the reservoir in the hydrocarbon discharging process to the content of inorganic elements which are specific to the reservoir rock particles and remain stable in a hot liquid system and are not migrated by fluid, at this time, based on the planar distribution of the chemical element tracing index value of the target layer of a research area, the dominant migration direction of the hydrocarbon-containing fluid can be determined by the following modes:
and determining the direction in which the chemical element tracing index value gradually decreases as the dominant migration direction of the hydrocarbon-containing fluid based on the layer chemical element tracing index value plane distribution of the research area.
The method comprises the steps of determining chemical element tracing index values of reservoir rock core samples at different plane positions preferably by performing an X-ray diffraction full rock analysis mode on the reservoir rock core samples at the different plane positions; the X-ray diffraction full 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 can be obtained by adopting a conventional method, for example, based on the drilled 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.
Example 1
The embodiment provides a method for determining migration paths of stratum hydrocarbon-containing hot fluid, which aims at determining the direction of hydrocarbon-containing fluid of a triad hundred-and-one spring group in a slope region of a Leucon palace, 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 rock core samples at different plane positions of the target layer based on the drilled data of the research area; preparing a reservoir rock core sample into a powder sample and a sample sheet suitable for detection of a common microscope, a cathode luminescence microscope, a Scanning Electron Microscope (SEM) electron probe, LA-ICP-MS, XRF and the like;
wherein the reservoir core samples at different planar locations of the zone of interest comprise reservoir core samples of typical wells of different hydrocarbon display grades of the zone of interest.
Step 2: determining the kind of the parent (source rock) inorganic element 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 a source rock sample and a 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 the group components of asphaltene, aromatic hydrocarbon, non-hydrocarbon and asphaltene, and the results are shown in fig. 2A-2D; the content of inorganic elements in asphaltene which is a group component is analyzed in a key way;
step 2.2: based on the determination results of the content determination and the abundance ratio of different types of inorganic elements, the type of the parent inorganic element is determined;
as shown in fig. 2A-2D, the total content of inorganic elements of the crude oil in the example zone is linearly related to asphaltenes in the crude oil family components, but less related to non-hydrocarbons, non-hydrocarbons + asphaltenes, and aromatic hydrocarbons, because asphaltenes have higher molecular weight, more complex molecular structure, and more polarity than non-hydrocarbons; it is easier to provide conditions for the formation of the metal complex, thereby enriching the inorganic elements;
the analysis of an example area shows that the content of Fe and Mn in a binary hydrocarbon source rock stratum is high, and asphaltene in crude oil components of a ternary oil deposit is a main carrier of inorganic elements and is characterized by being rich in Mn, fe and Cr; the main elements of affinity are Mn, fe and the like which are determined by combining a hydrocarbon source rock sample and crude oil analysis.
Step 3: determining the types of inorganic elements enriched on the secondary large sides of the quartz particles based on a reservoir core sample of the quartz particles with the secondary large sides;
observing the rock characteristics of a reservoir rock core sample with secondary large-side quartz particles under a lens, and measuring quartz particles with two different scales of in-situ micro-areas and thin slices, and the main quantity and trace element content of the large-side quartz particles; the method specifically comprises the following steps:
step 3.1: observing the lithology characteristics of quartz particles in the reservoir rock core sample by using a sample sheet under a microscope, and screening the reservoir rock core sample with quartz particles with secondary large edges;
specifically, the main components of the reservoir core sample (observed by adopting a sample sheet) are observed under a microscope by using single polarized light and orthogonal light, whether corrosion phenomenon exists or not, whether quartz enlarged edges, fluid inclusion filling and the like exist or not; distinguishing quartz enlarged edge minerals in different periods by utilizing cathodoluminescence observation, and carrying out scanning electron microscope test to analyze the morphology of secondary quartz particles and the corrosion degree of the edges of the quartz particles; comprehensively judging whether the sample is subjected to strong water-rock interaction, and preferably selecting a reservoir core sample with obvious corrosion characteristics and quartz enlarged edge characteristics as a reservoir core sample with quartz particles with secondary enlarged edges in a target layer of a research area;
as shown in fig. 3A-3C: the reservoir rock core sample at the position of the AH2 well 3313.56m shows that quartz particles are corroded in an estuary shape and clay is bred and filled with inclusion bodies; the cathodoluminescence map of the reservoir core sample at 2824.45m of the AH11 well shows that the quartz enlarged edge is obvious; the MA18 well 3905.78m reservoir rock core sample scanning electron microscope shows that quartz enlarged edges and newly generated quartz are obvious; from this, the example zone reservoir core samples reflect strong "fluid-rock" interactions in the hydrocarbon fluid migration path, typical clayish, strong alteration and quartz secondary enlargement;
step 3.2: in a sample slice of a reservoir rock core sample with quartz particles with secondary large edges, delineating the quartz particles with secondary large edges, and detecting different inorganic element contents in the quartz particles and at different positions from the center of the particles to the edges of the particles;
the method comprises the steps of selecting a sample sheet with obvious secondary enlarged edges, utilizing an electronic probe to in-situ detect the inside of quartz particles and the content of inorganic elements with the main increased edges, and carrying out the steps in sequence from the center of the particles to the edges of the particles; considering that the trace element content is low, the in-situ measuring point detection difficulty is high, and the conventional electronic probe means are difficult to realize, so that the trace inorganic element content inside and on the enlarged side of quartz particles is determined by combining with a LA-ICP-MS (laser ablation-plasma mass spectrometer) method, and the detection is also carried out according to the sequence from the center of the particles to the edge of the particles;
in the example, cr, co, ni, sr and the contents of easily-migrating elements such as Mn, fe, al and the like are measured, the elements Mn and Fe of a parent source (hydrocarbon source rock) are detected, and an easily-migrating element content distribution diagram 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 large sides of the quartz particles based on the contents of different inorganic elements at different positions from the center of the particles to the edges of the particles;
as can be seen from fig. 4A to fig. 4D, in-situ elemental analysis in the example zone shows that the edge secondary and edge enrichment phenomenon occurs from the center (Q-1) to the enlarged edge (Q-2) of the quartz particles, and elements such as Mn, fe, al, co, ni, sr, W, etc., which indicates that a large amount of inorganic elements in the hydrocarbon-containing hydrothermal fluid passing through the reservoir can undergo chemical reaction at the periphery of the quartz particles to generate exchange of authigenic mineral-forming elements, and respond to fluid migration;
step 3.4: scanning sample slices of a reservoir rock core sample with secondary large 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 to determine the types of the inorganic elements enriched by the secondary large edges of the quartz particles;
specifically, on the basis of single-point in-situ elements, exciting X fluorescence signals of various elements in the surface sediment of a sheet-scale sample by using an XRF (X-ray fluorescence spectrometer) and carrying out detection analysis, wherein the count of the X fluorescence signals of a certain element in unit test time is used as a measured value of the element; observing the enrichment characteristic of the easily-migrating element around the quartz particles according to the continuous element reflection intensity and ratio change obtained by XRF sheet scanning; in the example, whether elements, such as Fe, mn, cr, sr, which are easily influenced by the hydrothermal fluid are aggregated around quartz particles or not is observed, and the larger scale of the quartz particles is further verified to be influenced by the hydrocarbon-containing hydrothermal fluid and the abnormal enrichment characteristic of the element content; the results are shown in FIGS. 5A-5I;
as can be seen from fig. 5A to 5I, the distribution of the elements in the sample sheet exhibits a non-uniform characteristic, and a significant element aggregation phenomenon is seen; elements such as Mn, fe, ti and the like which are easily influenced by the hot liquid fluid all show obvious aggregation or filling phenomenon around quartz particles, which shows that the elements form abnormally high element content points at the edges of the particles under the influence of the hot liquid fluid;
as is clear from the results of the steps 3.1 to 3.4, the types of inorganic elements which are concentrated on the secondary large side of the quartz particles include Mn, fe, etc.
Step 4: determining inorganic elements in the hydrocarbon source layer that are characteristic and that are exchanged with reservoir rock particles forming elements when flowing through the reservoir during hydrocarbon removal;
specifically: inorganic elements which are used as both the parent inorganic elements and the inorganic elements enriched on the secondary large sides of the quartz particles are selected based on the types of the parent inorganic elements and the types of the inorganic elements enriched on the secondary large sides of the quartz particles, and are used as inorganic elements which are peculiar in a hydrocarbon source layer and are exchanged with rock particles of the reservoir layer when flowing through the reservoir layer in the hydrocarbon discharging process.
Step 5: constructing a chemical element trace index based on inorganic elements in the hydrocarbon source layer that are characteristic and form element exchanges with reservoir rock particles as they flow through the reservoir during hydrocarbon removal;
the relative content of inorganic elements which are specific in the hydrocarbon source layer and are exchanged with reservoir rock particles forming elements when flowing through the reservoir layer in the hydrocarbon discharging process is specifically MnO/Zr, wherein Mn is the inorganic elements which are specific in the hydrocarbon source layer and are exchanged with the reservoir rock particles forming elements when flowing through the reservoir layer in the hydrocarbon discharging process, zr is the inorganic elements which are very inactive in chemical activity and are usually stable in a hydrothermal system and are not easy to be migrated by fluid.
Step 6: acquiring the plane distribution of the trace index values of the target layer chemical elements of the research area; the method specifically comprises the following steps:
step 6.1: determining chemical element tracing index values of reservoir rock core samples at different plane positions;
specifically, carrying out X-ray diffraction full rock analysis (XRD) on powder samples of reservoir rock core samples at different plane positions of a target layer of a research area to obtain chemical element tracing index MnO/Zr values of the reservoir rock core samples;
step 6.2: and (3) based on the determined chemical element trace index MnO/Zr values of the reservoir rock core samples at different plane positions, compiling a plane distribution contour map (shown in figure 6) of the chemical element trace index MnO/Zr values of the target layer of the research area.
Step 7: determining the dominant migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values of the research area;
specifically, determining the direction in which the trace index value of the chemical element gradually decreases as the dominant migration direction of the hydrocarbon-containing fluid; the results are shown in FIG. 6; as can be seen from FIG. 6, the preferred trace index MnO/Zr in the example region gradually decreases from the high value region of the Ma18 and Da10 wells in the south to the north, west and east of the periphery in the direction of the slope (the red arrow shows the dominant path).
Step 8: verifying the dominant migration direction of hydrocarbon-containing fluid by using the formation characteristics, the oil gas flow well and the pressure coefficient;
the contour line of the pressure coefficient is shown in fig. 6; and (3) the dominant migration direction of the hydrocarbon-containing fluid determined in the step (7) is completely matched with the reservoir formation structure and the oil-gas flow well of the known oil reservoir, and the dominant migration direction of the hydrocarbon-containing fluid is also highly matched with the contour line of the pressure coefficient.
In the above embodiment, the inventor utilizes quartz minerals with the widest distribution and highest content in land source clastic rock to analyze and secondarily generate element characteristics with different scales such as large-edge in-situ micro-areas, thin slices, all rocks and the like, constructs parent (hydrocarbon source rock) sex element indexes, establishes the relationship between element content change and migration distance, and forms a novel method for tracing hydrocarbon-containing fluid migration by utilizing autogenous quartz inorganic elements.
The embodiment applies the method for determining the migration path of the stratum hydrocarbon-containing hot fluid to the judgment of the direction of hydrocarbon-containing fluid of the triad hundred springs of the slope area of the Leucavium marc lake; based on the composition and content change of the authigenic quartz element, the migration direction of hydrocarbon-containing fluid can be effectively tracked, and Mn/Zr, Y/Ho and the like are constructed as effective element indexes for indicating the migration and aggregation path; the method is used for carrying out fine tracking on the dominant transportation and aggregation paths and directions of hydrocarbon-containing fluid in east and west slope areas of the Lepidium meyenii, effectively guiding exploration production, mainly guiding fine evaluation and target deployment of a far-source oil-gas formation storage area outside the east slope area, combining researches of reservoir formation, reservoir spreading and the like, and newly realizing scale reserves of near hundred million tons. The practical feasibility of the technical scheme provided by the invention is verified, and the popularization and application prospect is realized.
The principles and embodiments of the present invention have been described in detail with reference to specific examples, which are provided to facilitate understanding of the method and core ideas of the present invention; meanwhile, as those skilled in the art will have variations in the specific embodiments and application scope in accordance with the ideas of the present invention, the present description should not be construed as limiting the present invention in view of the above.
Claims (11)
1. A method of determining a migration path of a hydrocarbon-bearing hot fluid in a subterranean formation, wherein the method comprises:
constructing a chemical element trace index based on inorganic elements in the hydrocarbon source layer that are characteristic and form element exchanges with reservoir rock particles as they flow through the reservoir during hydrocarbon removal; the chemical element tracing index obtained by construction is the ratio of the content of inorganic elements which are special in a hydrocarbon source layer and form element exchange with reservoir rock particles when flowing through the reservoir in the hydrocarbon discharging process to the content of inorganic elements which are special in the reservoir rock particles and keep stable and not migrated by fluid in a hot liquid system;
acquiring the plane distribution of the trace index values of the target layer chemical elements of the research area;
determining the dominant migration direction of the hydrocarbon-containing fluid based on the planar distribution of the target layer chemical element tracing index values of the research area;
wherein inorganic elements in the hydrocarbon source layer that are specific and that are exchanged with reservoir rock particles forming elements when flowing through the reservoir during hydrocarbon removal are determined by the following method:
acquiring a hydrocarbon source rock sample of a research area, a crude oil sample of a target layer and a reservoir rock core sample of quartz particles with a secondary large edge in the presence of the target layer; wherein the reservoir core sample with the quartz particles with the secondary large edges has corrosion characteristics and/or is filled with fluid inclusion;
determining the type of the parent inorganic element based on the source rock sample and the crude oil sample; wherein the parent source refers to a parent hydrocarbon source rock;
in the reservoir rock core sample with the quartz particles with the secondary large edges, the quartz particles with the secondary large edges are defined, and the content of different inorganic elements in the quartz particles and at different positions from the center of the particles to the edges of the particles is detected; determining the types of inorganic elements enriched on the secondary large sides of the quartz particles based on the contents of different inorganic elements at different positions from the center of the particles to the edges of the particles;
selecting inorganic elements which are used as both the parent inorganic elements and the inorganic elements enriched on the secondary large sides of the quartz particles and are used as inorganic elements which are peculiar 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 based on the types of the parent inorganic elements and the types of the inorganic elements enriched on the secondary large sides of the quartz particles;
wherein the inorganic elements in the hydrocarbon source layer that are specific and that are exchanged with reservoir rock particles forming elements when flowing through the reservoir during hydrocarbon removal include at least one of Mn, fe, and Y;
wherein the inorganic elements characteristic of the reservoir rock particles and remaining stable in the hot liquid system from fluid migration include Zr and/or Ho;
wherein the chemical element tracing index obtained by construction is at least one of Mn/Zr, Y/Ho and MnO/Zr.
2. The determination method according to claim 1, wherein determining the kind of the parent inorganic element based on the source rock sample and the crude oil sample includes:
determining the content of different inorganic elements and the abundance ratio of the hydrocarbon source rock sample and the crude oil sample;
based on the determination results of the content of the inorganic elements of different types and the abundance ratio, the type of the parent inorganic element is determined.
3. The determination method of claim 2, wherein the determination of the content of different kinds of inorganic elements on the crude oil sample comprises determination of the content of inorganic elements in different family components in the crude oil sample, the family components including at least one of aromatic hydrocarbons, non-hydrocarbons, and asphaltenes.
4. The determination method according to claim 2, wherein the determination of the content of the different kinds of inorganic elements and the determination of the abundance ratio are performed by using a plasma atomic emission spectrometry.
5. The determination method according to claim 1, wherein,
detecting the contents of main inorganic elements in different positions from the center of the particle to the edge of the particle in the quartz particle and increasing the edge of the quartz particle by an electronic probe in-situ detection mode;
the detection of the trace inorganic element content in different inorganic elements at different positions from the center to the edge of the quartz particle is carried out by combining an electron probe in-situ detection method with a laser ablation-plasma mass spectrometer method.
6. The determination method according to claim 1, wherein determining the kind of the inorganic element enriched in the secondary large side of the quartz particles based on the reservoir core sample of the quartz particles in which the secondary large side exists comprises:
and preparing the reservoir rock core sample with the secondary large edges into sample slices, and scanning the sample slices to obtain sample slice plane distribution 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 by the secondary large edges of the quartz particles.
7. The method according to claim 6, wherein scanning the sample flakes to obtain the planar distribution of the sample flakes with different inorganic element contents is performed by using an X-ray fluorescence spectrometer.
8. The method of determining of claim 1, wherein the obtaining a layer chemical element tracer index value planar distribution of interest comprises:
obtaining reservoir rock core samples at different plane positions of a target layer of a research area;
determining chemical element tracer index values of reservoir core samples at the different planar locations;
and determining the target layer chemical element tracing index value plane distribution of the research area based on the determined chemical element tracing index values of the reservoir rock core samples at the different plane positions.
9. The determination method according to claim 8, wherein determining the chemical element tracing index value of the reservoir core sample at the different plane position is performed by performing an X-ray diffraction full rock analysis method on the reservoir core sample at the different plane position.
10. The determining method according to claim 8, wherein the determining the target zone chemical element tracing index value planar distribution based on the determined chemical element tracing index values of the reservoir core samples at the different planar positions includes:
and compiling a chemical element tracing index value plane distribution contour map of the target layer of the research area based on the determined chemical element tracing index values of the reservoir rock core samples at different plane positions.
11. The determination method of claim 1, wherein the formation hydrocarbon-bearing hot fluid migration path determination method further comprises:
and verifying the dominant migration direction of the hydrocarbon-containing fluid by using the reservoir formation characteristics and/or the pressure coefficient contour lines and/or the oil-gas flow wells and the like.
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