CN110259439B - Method and device for evaluating carbonate rock fault closure evolution history - Google Patents
Method and device for evaluating carbonate rock fault closure evolution history Download PDFInfo
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- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 214
- 239000011435 rock Substances 0.000 title claims abstract description 65
- 238000000034 method Methods 0.000 title claims abstract description 51
- 239000012530 fluid Substances 0.000 claims abstract description 85
- 238000007789 sealing Methods 0.000 claims abstract description 36
- 230000008569 process Effects 0.000 claims abstract description 17
- 230000015572 biosynthetic process Effects 0.000 claims description 20
- 238000011084 recovery Methods 0.000 claims description 19
- 238000004088 simulation Methods 0.000 claims description 18
- 239000012267 brine Substances 0.000 claims description 14
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims description 14
- 238000010276 construction Methods 0.000 claims description 12
- 230000005484 gravity Effects 0.000 claims description 10
- 238000004364 calculation method Methods 0.000 claims description 9
- 239000010410 layer Substances 0.000 claims description 9
- 238000007710 freezing Methods 0.000 claims description 6
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- 230000001133 acceleration Effects 0.000 claims description 5
- 230000015556 catabolic process Effects 0.000 claims description 5
- 238000006731 degradation reaction Methods 0.000 claims description 5
- 230000004907 flux Effects 0.000 claims description 5
- 229910052500 inorganic mineral Inorganic materials 0.000 claims description 5
- 239000007788 liquid Substances 0.000 claims description 5
- 239000011707 mineral Substances 0.000 claims description 5
- 239000004576 sand Substances 0.000 claims description 5
- 238000012360 testing method Methods 0.000 claims description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 5
- 239000012791 sliding layer Substances 0.000 claims description 3
- 238000005755 formation reaction Methods 0.000 claims 7
- 229930195733 hydrocarbon Natural products 0.000 abstract description 4
- 239000004215 Carbon black (E152) Substances 0.000 abstract description 3
- -1 carbonate hydrocarbon Chemical class 0.000 abstract 1
- 238000010586 diagram Methods 0.000 description 7
- 229910052625 palygorskite Inorganic materials 0.000 description 5
- 230000000694 effects Effects 0.000 description 4
- 238000009529 body temperature measurement Methods 0.000 description 3
- 238000009933 burial Methods 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 238000011156 evaluation Methods 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
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- 238000013508 migration Methods 0.000 description 3
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- 238000012986 modification Methods 0.000 description 2
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- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 238000005299 abrasion Methods 0.000 description 1
- 238000009825 accumulation Methods 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 238000005056 compaction Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000010587 phase diagram Methods 0.000 description 1
- 238000013031 physical testing Methods 0.000 description 1
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- 238000011160 research Methods 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
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- 239000004079 vitrinite Substances 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/20—Design optimisation, verification or simulation
- G06F30/23—Design optimisation, verification or simulation using finite element methods [FEM] or finite difference methods [FDM]
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F2111/00—Details relating to CAD techniques
- G06F2111/04—Constraint-based CAD
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- Environmental & Geological Engineering (AREA)
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Abstract
The embodiment of the invention provides a method and a device for evaluating carbonate fault closed evolution history, and belongs to the field of oil-gas exploration. The method comprises the following steps: recovering a fluid pressure evolution history of a carbonate reservoir based on present-day pressure distribution characteristics of the carbonate reservoir; recovering the evolution history of the magnitude and direction of the normal stress of the area of the carbonate reservoir; recovering the evolution history of the paleo-parameters of the carbonate fault; and calculating the sealing coefficient of the carbonate rock fault according to the fluid pressure evolution history of the carbonate rock reservoir, the evolution history of the normal stress magnitude and direction of the region of the carbonate rock reservoir and the evolution history of the paleoparameters of the carbonate rock fault so as to reconstruct the sealing evolution history of the carbonate rock fault. The method can simply, accurately and quickly reconstruct the closed evolution history of the carbonate fault so as to reveal the evolution process of the carbonate hydrocarbon reservoir oil and gas reservoir related to the fault.
Description
Technical Field
The invention relates to the field of oil and gas exploration, in particular to a method and a device for evaluating carbonate fault closed evolution history.
Background
Ancient deep carbonate oil and gas fields occupy an important position in oil and gas resources in China, wherein carbonate oil and gas reservoirs related to faults are main types. The fault plays an important role in the carbonate reservoir, and the formation and the evolution of the fault not only control the development and the evolution of the structural trap, but also have a good transformation effect on a deep carbonate reservoir. In addition, the fault controls the migration and accumulation of oil and gas in the carbonate oil and gas reservoir, and the carbonate oil and gas reservoir can be used as an advantageous migration channel for oil and gas migration and can also be used as a lateral shielding condition to block the oil and gas. After the oil and gas are filled, the sealing property of the fault also controls the storage of the oil and gas reservoir. If the fault is in a static state and the sealing performance is good after the oil gas is reserved, the later-period storage of the oil gas is facilitated; conversely, a later active fault will allow the early charge of hydrocarbons to escape and be preserved.
However, at present, fault sealing evaluation is mostly limited to a clastic rock stratum smeared by mudstone, the research on the internal structure and the sealing mechanism of a carbonate fault is relatively less, and an effective evaluation method for the fault sealing of the carbonate rock is not available at present. Meanwhile, the 'fault mud' formed by the carbonate fault nucleus is mostly the result of the abrasion effect of the brittle carbonate, and the prediction and evaluation cannot be carried out by a method based on clastic rock formation mudstone smearing, such as a mudstone smearing factor (SSF), a mudstone smearing Coefficient (CSP) and a fault mud ratio (SGR). Therefore, for the purpose of defining the deep carbonate reservoir evolution process, the method for quantitatively, simply, conveniently and accurately evaluating the closed evolution history of the carbonate fault is a technical problem which is urgently needed to be solved at present.
Disclosure of Invention
The embodiment of the invention aims to provide a method and a device for evaluating the closed evolution history of a carbonate rock fault, which can simply, accurately and quickly reconstruct the closed evolution history of the carbonate rock fault so as to reveal the hydrocarbon reservoir evolution process of the carbonate rock hydrocarbon reservoir related to the fault.
In order to achieve the above object, an embodiment of the present invention provides a method for evaluating a carbonate fault closed evolution history, the method including: recovering a fluid pressure evolution history of a carbonate reservoir based on present-day pressure distribution characteristics of the carbonate reservoir; simulating the tectonic stress fields of different historical periods according to the tectonic characteristics and the tectonic evolution process of the carbonate reservoir so as to recover the evolution history of the magnitude and the direction of the normal stress of the area of the carbonate reservoir; acquiring an evolution history of paleoparameters of the carbonate rock fault by performing paleotectonic restoration on a section perpendicular to the trend of the carbonate rock fault, wherein the paleoparameters comprise paleoburial depth, paleotrend and tendency of the fault and paleodip; and calculating the sealing coefficient of the carbonate rock fault according to the fluid pressure evolution history of the carbonate rock reservoir, the evolution history of the normal stress magnitude and direction of the region of the carbonate rock reservoir and the evolution history of the paleoparameters of the carbonate rock fault so as to reconstruct the sealing evolution history of the carbonate rock fault.
Optionally, the present-day pressure profile of the carbonate reservoir is determined according to the following steps: collecting formation pressure test data of a well; and analyzing the depth-pressure relationship based on the collected data to determine present day pressure distribution characteristics of the carbonate reservoir.
Optionally, the recovering the history of fluid pressure evolution of the carbonate reservoir based on the present-day pressure distribution characteristics of the carbonate reservoir comprises: observing host minerals and occurrence of inclusion; acquiring basic parameters of the paleo-pressure, wherein the basic parameters comprise uniform temperature of an oil inclusion and a brine inclusion of the same period, salinity and freezing point temperature of the brine inclusion and gas-liquid ratio of the oil inclusion; calculating fluid pressures of the carbonate reservoir in different geological historical periods according to the basic parameters by taking the components of the current oil and gas reservoir as initial components; according to main parameters in the carbonate reservoir fluid pressure simulation, performing the carbonate reservoir fluid pressure simulation to obtain a carbonate reservoir fluid pressure curve, wherein the main parameters may include: formation age, lithology combination, amount of degradation, history of thermal flux evolution, and rock thermal conductivity; and correcting the simulated carbonate reservoir fluid pressure curve by taking the calculated fluid pressures of different geological historical periods as constraint conditions.
Optionally, the simulating the formation stress fields of different historical periods according to the formation characteristics and the formation evolution process of the carbonate reservoir to recover the evolution history of the magnitude and direction of the normal stress of the region of the carbonate reservoir includes: establishing geological models of different periods through analyzing the structural characteristics and structural evolution history of the carbonate reservoir; dividing finite elements of geological models in different periods; and simulating the tectonic stress fields in different periods by using simulation software according to the divided geological models in different periods to obtain the magnitude and direction of the normal stress of the region where the carbonate reservoir is located in different geological historical periods so as to recover the evolution history of the magnitude and direction of the normal stress of the region where the carbonate reservoir is located.
Optionally, the restoration of the ancient structure of the profile perpendicular to the trend of the carbonate fault includes the restoration of the ancient burial depth of the carbonate fault, the ancient trend and tendency of the fault, and the evolution history of the ancient dip angle: selecting a section perpendicular to the trend of the carbonate fault, wherein the selected section is a section with one end not subjected to structural deformation; determining a sliding layer and a fault layer of the profile based on the region construction characteristics and the construction evolution process; selecting a corresponding balance method according to the structural background of the area where the carbonate reservoir is located, compacting or de-compacting and correcting the carbonate reservoir, and selecting a straight line perpendicular to the layer surface as a nail line at one end of the selected section where structural deformation does not occur; balancing the selected profile using a corresponding balancing model in combination with the slip and fault layers, the nail line based on a construction stress environment and a construction style; and after balancing the selected section, reading the paleo-parameters of the fault in each period based on the structural sections in different geological history periods, thereby recovering the evolution history of the paleo-parameters of the carbonate fault.
Optionally, the sealing coefficient of the carbonate fault is calculated according to the following formula:
wherein, IsThe fault sealing coefficient is dimensionless; pwIs a fluidPressure in MPa; g is the acceleration of gravity, and the unit is 9.8m/s2(ii) a H is the buried depth, and the unit is m; rhorIs the average density of the overburden in kg/m3；ρwIs the density of water in kg/m3G is gravity coefficient, theta is fault dip angle, α is included angle between fault trend and maximum horizontal principal stress, and sigmaMMaximum horizontal principal stress in MPa; sigmamIs the minimum level principal stress in MPa, where in the sealing coefficient IsWhen the fault is more than 1.0, the carbonate rock is in a closed state and has a closing coefficient IsAnd under the condition that the fault is not more than 1.0, the carbonate rock is in an open state.
Correspondingly, the embodiment of the invention also provides a device for evaluating the enclosed evolution history of the carbonate fault, which comprises the following steps: a first recovery module to recover a fluid pressure evolution history of a carbonate reservoir based on a present-day pressure distribution characteristic of the carbonate reservoir; the second recovery module is used for simulating the tectonic stress fields in different historical periods according to the tectonic characteristics and the tectonic evolution process of the carbonate reservoir so as to recover the evolution history of the magnitude and the direction of the normal stress of the area where the carbonate reservoir is located; the third recovery module is used for acquiring the evolution history of paleo-parameters of the carbonate fault by performing paleotectonic recovery on a section perpendicular to the trend of the carbonate fault, wherein the paleo-parameters comprise paleoburial depth, paleotrend and trend of the fault and paleodip; and the calculation module is used for calculating the sealing coefficient of the carbonate rock fault according to the fluid pressure evolution history of the carbonate rock reservoir, the evolution history of the normal stress magnitude and direction of the region of the carbonate rock reservoir and the evolution history of the paleoparameter of the carbonate rock fault so as to rebuild the sealing evolution history of the carbonate rock fault.
Optionally, the first module for recovering the history of fluid pressure evolution of the carbonate reservoir according to the following steps comprises: observing host minerals and occurrence of inclusion; acquiring basic parameters of the paleo-pressure, wherein the basic parameters comprise uniform temperature of an oil inclusion and a brine inclusion of the same period, salinity and freezing point temperature of the brine inclusion and gas-liquid ratio of the oil inclusion; calculating fluid pressures of the carbonate reservoir in different geological historical periods according to the basic parameters by taking the components of the current oil and gas reservoir as initial components; according to main parameters in the carbonate reservoir fluid pressure simulation, performing the carbonate reservoir fluid pressure simulation to obtain a carbonate reservoir fluid pressure curve, wherein the main parameters may include: formation age, lithology combination, amount of degradation, history of thermal flux evolution, and rock thermal conductivity; and correcting the simulated carbonate reservoir fluid pressure curve by taking the calculated fluid pressures of different geological historical periods as constraint conditions.
Optionally, the calculation module calculates the sealing coefficient of the carbonate fault according to the following formula:
wherein, IsThe fault sealing coefficient is dimensionless; pwIs the fluid pressure in MPa; g is the acceleration of gravity, and the unit is 9.8m/s2(ii) a H is the buried depth, and the unit is m; rhorIs the average density of the overburden in kg/m3；ρwIs the density of water in kg/m3G is gravity coefficient, theta is fault dip angle, α is included angle between fault trend and maximum horizontal principal stress, and sigmaMMaximum horizontal principal stress in MPa; sigmamIs the minimum level principal stress in MPa, where in the sealing coefficient IsWhen the fault is more than 1.0, the carbonate rock is in a closed state and has a closing coefficient IsAnd under the condition that the fault is not more than 1.0, the carbonate rock is in an open state.
Accordingly, embodiments of the present invention also provide a machine-readable storage medium having stored thereon instructions for enabling a machine to perform the above-described method for evaluating a closed evolutionary history of a carbonate fault.
By the technical scheme, the fluid pressure evolution history of the carbonate reservoir is restored, the normal stress of different geological historical periods is restored, the paleoparameters of faults of different geological historical periods are obtained through paleostructural restoration, finally, the fault closure coefficient is calculated based on the paleofluid pressure, the normal stress of different geological historical periods and the paleoparameters of the faults, and the closure of each part and each period of the carbonate fault is quantitatively evaluated, so that the fault closure evolution history can be simply, accurately and quickly established, and the carbonate oil and gas reservoir oil and gas evolution process related to the fault is revealed.
Additional features and advantages of embodiments of the invention will be set forth in the detailed description which follows.
Drawings
The accompanying drawings, which are included to provide a further understanding of the embodiments of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the embodiments of the invention without limiting the embodiments of the invention. In the drawings:
FIG. 1 shows a schematic flow diagram of a method for evaluating a carbonate fault seal evolution history according to an embodiment of the invention;
FIG. 2 is a schematic diagram illustrating the pressure recovery results of the fluid enclosure in one embodiment;
FIG. 3 is a schematic diagram illustrating a history of fluid pressure evolution of a carbonate reservoir in one embodiment;
FIG. 4(a) shows a schematic cross-sectional view perpendicular to a carbonate fault in an embodiment;
FIG. 4(b) shows a closing coefficient curve of calculated points at different depths on a controlled-deposit fault corresponding to the gas flow well threo 4 on the fault section of FIG. 4 (a); and
FIG. 5 shows a block diagram of an apparatus for evaluating a carbonate fault seal evolution history according to an embodiment of the invention.
Detailed Description
The following detailed description of embodiments of the invention refers to the accompanying drawings. It should be understood that the detailed description and specific examples, while indicating embodiments of the invention, are given by way of illustration and explanation only, not limitation.
FIG. 1 shows a schematic flow diagram of a method for evaluating a carbonate fault seal evolution history according to an embodiment of the invention. As shown in fig. 1, an embodiment of the present invention provides a method for evaluating a carbonate fault closed evolution history, which includes steps S110 to S140.
At step S110, a fluid pressure evolution history of the carbonate reservoir is recovered based on present-day pressure distribution characteristics of the carbonate reservoir.
The history of fluid pressure evolution of the carbonate reservoir may for example represent the fluid pressure of the carbonate reservoir at different times in a curve or similar manner.
In particular, formation pressure test data may be collected for drilling, which may include drill pipe formation test data and formation test pressure data. The depth-pressure relationship is analyzed based on the collected data to clarify present day pressure distribution characteristics of the carbonate reservoir.
After determining the present pressure distribution characteristics of the carbonate reservoir, the fluid pressure evolution history of the carbonate reservoir can be recovered by using a fluid inclusion thermodynamics simulation method in combination with a basin simulation method. It specifically comprises the following steps, wherein the fluid inclusion thermo-dynamics simulation involves steps (1) to (3) listed below, and the basin simulation involves step (4) listed below:
(1) and performing lithology observation on the fluid inclusion of the carbonate reservoir (including observation of main minerals and occurrence states of the inclusion) to preliminarily judge the formation period of each inclusion of the carbonate reservoir.
(2) The method comprises the steps of obtaining basic parameters of paleopressure, wherein the basic parameters comprise the uniform temperature of an oil inclusion and a brine inclusion in the same period, the salinity and freezing point temperature of the brine inclusion and the gas-liquid ratio of the oil inclusion, specifically, carrying out microscopic temperature measurement on the oil inclusion and the brine inclusion in different periods in a carbonate reservoir, wherein the measured temperature comprises the uniform temperature of the oil inclusion and the brine inclusion in the same period, the salinity and freezing point temperature of the brine inclusion, and when carrying out temperature measurement, selecting an inclusion temperature measurement sample according to the principle that the inclusion is large (for example, the volume of an individual is larger than a certain value), regular in shape and clear in boundary.
(3) And calculating the fluid pressure of the carbonate reservoir in different geological historical periods according to the measured basic parameters by taking the components of the current oil and gas reservoir as initial components, wherein the current fluid pressure can be obtained through actual measurement. FIG. 2 is a graph illustrating the pressure recovery of the fluid enclosure in one embodiment. As shown in fig. 2, fluid inclusion gulf pressure recovery is primarily obtained on a pressure-temperature phase diagram based on the intersection of the oil inclusion isocontour and the saline inclusion isocontour. The five-pointed star in fig. 2 represents the intersection of the oil inclusion isovolumetric line and the brine inclusion isovolumetric line, which represents the carbonate reservoir fluid pressure over the geologic history period. Alternatively, the fluid pressures for different geological history periods may be calculated by simulation using PVTsim software.
(4) According to main parameters in the carbonate reservoir fluid pressure simulation, performing the carbonate reservoir fluid pressure simulation to obtain a carbonate reservoir fluid pressure curve, wherein the main parameters may include: formation age, lithology combination, amount of degradation, history of thermal flux evolution, and rock thermal conductivity, among others. The fluid pressure curve represents the fluid pressure at different times. Optionally, basimodo software may be used to perform the carbonate reservoir fluid pressure simulation, during the simulation, the compaction model may be an inverse model, the pressure calculation model may be a bmo fluid model, the porosity calculation model may be a bmo 2-D fluid model, and the permeability calculation model may be a Power Function model. The simulation results can be constrained by measured Ro (vitrinite reflectance) data, measured porosity data, measured pressure data, and pressure data calculated by the fluid inclusion gulf pressure method to ensure the accuracy of the results. Further optionally, the simulated carbonate reservoir fluid pressure curve may be corrected using the calculated fluid pressures for different geological historical periods as constraints.
A history of fluid pressure evolution of the carbonate reservoir may be obtained according to steps (1) - (4) above. Fig. 3 shows a schematic diagram of the history of fluid pressure evolution of a carbonate reservoir in an embodiment showing the variation curves of void pressure and hydrostatic pressure at different times, where the abscissa represents different times and the ordinate represents fluid pressure. The pore pressure variation curve shown in fig. 3 is the fluid pressure evolution history of the carbonate reservoir, where the five-pointed star represents the paleo-fluid pressure for inclusion recovery, i.e. the fluid pressures for different geological history periods calculated in step (4). The right-most five-pointed star in the figure is the measured fluid pressure at present.
In step S120, according to the structural characteristics and the structural evolution process of the carbonate reservoir, structural stress fields of different historical periods are simulated to recover the evolution history of the magnitude and direction of the normal stress of the region where the carbonate reservoir is located.
The history of the evolution of the magnitude and direction of the positive stress may for example be represented in a curve or similar manner as the magnitude and direction of the positive stress in the region of the carbonate reservoir during the different geological history periods. Step S120 may specifically include the following steps:
(1) establishing geological models of different periods through analyzing the structural characteristics of the carbonate reservoir and the fluid pressure evolution history;
(2) dividing finite elements of geological models in different periods, giving reasonable rock mechanical parameters to the models through physical testing and well logging information, and applying reasonable load, constraint and boundary conditions;
(3) and simulating the tectonic stress fields in different periods by using simulation software according to the divided geological models in different periods to obtain the magnitude and direction of the normal stress of the region where the carbonate reservoir is located in different geological historical periods so as to recover the evolution history of the magnitude and direction of the normal stress of the region where the carbonate reservoir is located.
In step S130, an evolution history of paleo-parameters of the carbonate fault, which may include paleoburial depth, paleotrend and trend of fault, and paleodip, is obtained by performing paleostructural restoration on a section perpendicular to the trend of the carbonate fault.
The history of the evolution of the paleo-parameters may represent the paleo-parameters of faults of different periods in a curved or similar manner. Step S130 may specifically include the following steps:
(1) a profile perpendicular to the orientation of the carbonate fault is selected. One end of the selected profile is preferably free of structural deformation to facilitate determination of the staple line at equilibrium.
(2) Determining a sliding layer and a fault layer of the profile based on the region construction characteristics and the construction evolution process.
(3) And selecting a corresponding balance method according to the structural background of the area of the carbonate reservoir, compacting or de-compacting and correcting the carbonate reservoir, and selecting a straight line vertical to the layer surface as a nail line at one end of the selected section where structural deformation does not occur.
(4) Balancing the selected profile using a corresponding balancing model in combination with the slip layer and fault plane, the nail line based on the construction stress environment and the construction style.
(5) And after balancing the selected section, reading the paleo-parameters of the fault in each period based on the structural sections in different geological history periods, thereby recovering the evolution history of the paleo-parameters of the carbonate fault.
In step S140, calculating an evolution history of a sealing coefficient of the carbonate rock fault according to the fluid pressure evolution history of the carbonate rock reservoir, the evolution history of the magnitude and direction of the normal stress of the region where the carbonate rock reservoir is located, the paleoburial depth of the carbonate rock fault, the paleotrend and tendency of the fault, and the evolution history of the paleodip, so as to reconstruct the closed evolution history of the carbonate rock fault.
And based on the palygorskite pressure recovery result, calculating the fault closure coefficient by combining the palygorskite burial depth of the fault, the palygorskite trend and tendency of the fault, palygorskite dip angle parameters and the palygorskite reservoir pressure result, and determining the fault closure in different geological history periods so as to reconstruct the carbonate rock fault closure evolution history. The method specifically comprises the following steps:
(1) the fluid pressure has a decisive effect on the opening of the fault, namely, the fault is opened when the fluid pressure in the fault zone is greater than or equal to the normal stress of the fault, and the fault is closed when the fluid pressure in the fault zone is less than or equal to the normal stress of the fault. Then the fault blocking coefficient I can be usedsTo evaluate the sealing performance of the fault, which is defined as the ratio of normal stress to fluid pressure applied to the fault surface, and sealing coefficient IsThe calculation formula of (a) is as follows:
in the formula: i issThe fault sealing coefficient is dimensionless; sigma is positive stress, and the unit is MPa; pwIs the fluid pressure in MPa; g is the acceleration of gravity, and the unit is 9.8m/s2(ii) a H is the buried depth, and the unit is m; rhorIs the average density of the overburden in kg/m3；ρwIs the density of water in kg/m3G is gravity coefficient, theta is fault dip angle, α is included angle between fault trend and maximum horizontal principal stress, and sigmaMMaximum horizontal principal stress in MPa; sigmamIs the minimum horizontal principal stress in MPa.
If coefficient of confinement IsIf the fault is larger than 1.0, the fault is in a closed state, so that the oil gas can be stored after being filled; if coefficient of confinement IsWhen the oil gas is less than 1.0, the fault is in an open state, and the oil gas filled in the reserve period escapes along the fault opened in the later period and cannot be stored.
(2) Calculating the sealing coefficient I of the fault according to the formula (1) based on the paleoresponse pressure recovery result, the paleoparameters of the fault and the paleofluid pressure result of the reservoirsAnd determining the sealing performance of the carbonate rock fault in different geological history periods, and reconstructing the sealing evolution history of the fault.
FIG. 4(a) shows a schematic cross-sectional view perpendicular to a carbonate fault in one embodiment. Fig. 4(b) shows a closing coefficient curve of calculated points at different depths on a controlled-deposit fault corresponding to the gas flow well su 4 on the fault section of fig. 4 (a). In fig. 4(b), the sealing coefficients of the calculation points (point 1 and point 2) at different depths on the reservoir control fault corresponding to the oil-gas flow well su 4 are all greater than 1.0 in different geological history periods (30Ma-0Ma), which indicates that the reservoir control fault is always in a sealed state after oil-gas filling, and a good storage effect is achieved on the oil-gas reservoir.
The execution sequence of step S110, step S120 and step S130 may be arbitrary, and the embodiment of the present invention is not limited. According to the specific implementation steps of the embodiment of the invention, the closure of different parts and different periods of the same carbonate rock fault can be quantitatively evaluated, so that the oil-gas regulation and evolution process in the oil-gas reservoir is established.
FIG. 5 shows a block diagram of an apparatus for evaluating a carbonate fault seal evolution history according to an embodiment of the invention. As shown in fig. 5, an embodiment of the present invention further provides an apparatus for evaluating a history of closed evolution of a carbonate fault, which may include: a first recovery module 510 for recovering a fluid pressure evolution history of a carbonate reservoir based on a present-day pressure distribution characteristic of the carbonate reservoir; the second recovery module 520 is used for simulating the tectonic stress fields in different historical periods according to the tectonic characteristics and the tectonic evolution process of the carbonate reservoir so as to recover the evolution history of the magnitude and the direction of the normal stress of the area where the carbonate reservoir is located; a third recovery module 530, configured to obtain an evolution history of paleo-parameters of the carbonate fault by performing paleostructural recovery on a section perpendicular to a trend of the carbonate fault, where the paleo-parameters include paleo-burial depth, paleo-trend and trend of the fault, and paleo-dip; and a calculating module 540, configured to calculate a sealing coefficient of the carbonate fault according to the fluid pressure evolution history of the carbonate reservoir, the evolution history of the normal stress magnitude and direction of the region where the carbonate reservoir is located, and the evolution history of the paleo-parameters of the carbonate fault, so as to reconstruct the sealed evolution history of the carbonate fault.
The specific working principle and the benefits of the device for evaluating the closed evolution history of the carbonate fault provided by the embodiment of the invention are similar to those of the method for evaluating the closed evolution history of the carbonate fault provided by the embodiment of the invention, and the detailed description is omitted here.
Accordingly, embodiments of the present invention also provide a machine-readable storage medium having stored thereon instructions for enabling a machine to execute the method for evaluating a closed evolutionary history of a carbonate fault according to any of the embodiments of the present invention.
According to the embodiment of the invention, the fault closure coefficient is calculated based on the paleostructural stress field, paleofluid pressure and fault paleogenesis, and the closure of each part and each period of the carbonate rock fault is quantitatively evaluated, so that the fault closure evolution history is established, and the carbonate rock gas reservoir oil and gas evolution process related to the fault is disclosed.
The scheme provided by the embodiment of the invention is suitable for the carbonate rock fault coated by non-fault-plane mudstone, is not limited by a multi-stage structure evolution background and complex fluid power, is suitable for an early oil and gas exploration area and a late exploration and mature development area, and provides an effective and reliable new way for evaluating the closed evolution history of the fault of the ancient deep carbonate rock, thereby guiding the exploration and development of the deep carbonate rock related to the fault.
Although the embodiments of the present invention have been described in detail with reference to the accompanying drawings, the embodiments of the present invention are not limited to the details of the above embodiments, and various simple modifications can be made to the technical solutions of the embodiments of the present invention within the technical idea of the embodiments of the present invention, and the simple modifications all belong to the protection scope of the embodiments of the present invention.
It should be noted that the various features described in the above embodiments may be combined in any suitable manner without departing from the scope of the invention. In order to avoid unnecessary repetition, the embodiments of the present invention do not describe every possible combination.
Those skilled in the art will understand that all or part of the steps in the method according to the above embodiments may be implemented by a program, which is stored in a storage medium and includes several instructions to enable a single chip, a chip, or a processor (processor) to execute all or part of the steps in the method according to the embodiments of the present application. And the aforementioned storage medium includes: a U-disk, a removable hard disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a magnetic disk or an optical disk, and other various media capable of storing program codes.
In addition, any combination of various different implementation manners of the embodiments of the present invention is also possible, and the embodiments of the present invention should be considered as disclosed in the embodiments of the present invention as long as the combination does not depart from the spirit of the embodiments of the present invention.
Claims (8)
1. A method for evaluating a history of closed evolution of a carbonate fault, the method comprising:
recovering a fluid pressure evolution history of a carbonate reservoir based on present-day pressure distribution characteristics of the carbonate reservoir;
simulating the tectonic stress fields of different historical periods according to the tectonic characteristics and the tectonic evolution process of the carbonate reservoir so as to recover the evolution history of the magnitude and the direction of the normal stress of the area of the carbonate reservoir;
acquiring an evolution history of paleoparameters of the carbonate rock fault by performing paleotectonic restoration on a section perpendicular to the trend of the carbonate rock fault, wherein the paleoparameters comprise paleoburial depth, paleotrend and tendency of the fault and paleodip; and
calculating the sealing coefficient of the carbonate rock fault according to the evolution history of the fluid pressure of the carbonate rock reservoir, the evolution history of the normal stress magnitude and direction of the area where the carbonate rock reservoir is located and the evolution history of the paleoparameters of the carbonate rock fault so as to reconstruct the sealing evolution history of the carbonate rock fault, wherein the sealing coefficient of the carbonate rock fault is calculated according to the following formula:
wherein, IsThe fault sealing coefficient is dimensionless; pwIs the fluid pressure in MPa; g is the acceleration of gravity, and the unit is 9.8m/s2(ii) a H is the buried depth, and the unit is m; rhorIs the average density of the overburden in kg/m3；ρwIs the density of water in kg/m3G is gravity coefficient, theta is fault dip angle, α is included angle between fault trend and maximum horizontal principal stress, and sigmaMMaximum horizontal principal stress in MPa; sigmamIs the minimum horizontal principal stress in MPa,
wherein, in the sealing coefficient IsWhen the fault is more than 1.0, the carbonate rock is in a closed state and has a closing coefficient IsAnd under the condition that the fault is not more than 1.0, the carbonate rock is in an open state.
2. The method of claim 1, wherein the present day pressure profile characteristic of the carbonate reservoir is determined according to the following steps:
collecting formation pressure test data of a well; and
analyzing the depth-pressure relationship based on the collected data to determine present day pressure distribution characteristics of the carbonate reservoir.
3. The method of claim 1, wherein recovering the fluid pressure evolution history of the carbonate reservoir based on the present-day pressure distribution characteristic of the carbonate reservoir comprises:
observing host minerals and occurrence of inclusion;
acquiring basic parameters of the paleo-pressure, wherein the basic parameters comprise uniform temperature of an oil inclusion and a brine inclusion of the same period, salinity and freezing point temperature of the brine inclusion and gas-liquid ratio of the oil inclusion;
calculating fluid pressures of the carbonate reservoir in different geological historical periods according to the basic parameters by taking the components of the current oil and gas reservoir as initial components;
according to main parameters in the carbonate reservoir fluid pressure simulation, performing the carbonate reservoir fluid pressure simulation to obtain a carbonate reservoir fluid pressure curve, wherein the main parameters comprise: formation age, lithology combination, amount of degradation, history of thermal flux evolution, and rock thermal conductivity; and
and correcting the simulated carbonate reservoir fluid pressure curve by taking the calculated fluid pressures of different geological historical periods as constraint conditions.
4. The method of claim 1, wherein simulating formation stress fields of different historical periods according to the formation characteristics and the formation evolution process of the carbonate reservoir to recover the evolution history of the magnitude and direction of the normal stress of the region of the carbonate reservoir comprises:
establishing geological models of different periods through analyzing the structural characteristics and structural evolution history of the carbonate reservoir;
dividing finite elements of geological models in different periods; and
and simulating the tectonic stress fields in different periods by using simulation software according to the divided geological models in different periods to obtain the magnitude and direction of the normal stress of the region where the carbonate reservoir is located in different geological historical periods so as to recover the evolution history of the magnitude and direction of the normal stress of the region where the carbonate reservoir is located.
5. The method of claim 1, wherein the restoring the paleoburial depth of the carbonate fault, the paleotrend and the dip of the fault, and the history of the evolution of the paleodip by paleotectonic restoration of a section perpendicular to the trend of the carbonate fault comprises:
selecting a section perpendicular to the trend of the carbonate fault, wherein the selected section is a section with one end not subjected to structural deformation;
determining a sliding layer and a fault layer of the profile based on the region construction characteristics and the construction evolution process;
selecting a corresponding balance method according to the structural background of the area where the carbonate reservoir is located, compacting or de-compacting and correcting the carbonate reservoir, and selecting a straight line perpendicular to the layer surface as a nail line at one end of the selected section where structural deformation does not occur;
balancing the selected profile using a corresponding balancing model in combination with the slip and fault layers, the nail line based on a construction stress environment and a construction style;
and after balancing the selected section, reading the paleo-parameters of the fault in each period based on the structural sections in different geological history periods, thereby recovering the evolution history of the paleo-parameters of the carbonate fault.
6. An apparatus for evaluating a history of closed evolution of a carbonate fault, the apparatus comprising:
a first recovery module to recover a fluid pressure evolution history of a carbonate reservoir based on a present-day pressure distribution characteristic of the carbonate reservoir;
the second recovery module is used for simulating the tectonic stress fields in different historical periods according to the tectonic characteristics and the tectonic evolution process of the carbonate reservoir so as to recover the evolution history of the magnitude and the direction of the normal stress of the area where the carbonate reservoir is located;
the third recovery module is used for acquiring the evolution history of paleo-parameters of the carbonate fault by performing paleotectonic recovery on a section perpendicular to the trend of the carbonate fault, wherein the paleo-parameters comprise paleoburial depth, paleotrend and trend of the fault and paleodip; and
the calculation module is used for calculating the sealing coefficient of the carbonate rock fault according to the fluid pressure evolution history of the carbonate rock reservoir, the evolution history of the normal stress size and direction of the area where the carbonate rock reservoir is located and the evolution history of the paleoparameter of the carbonate rock fault so as to reconstruct the sealing evolution history of the carbonate rock fault,
wherein the calculation module calculates the sealing coefficient of the carbonate fault according to the following formula:
wherein, IsThe fault sealing coefficient is dimensionless; pwIs the fluid pressure in MPa; g is the acceleration of gravity, and the unit is 9.8m/s2(ii) a H is the buried depth, and the unit is m; rhorIs the average density of the overburden in kg/m3；ρwIs the density of water in kg/m3G is gravity coefficient, theta is fault dip angle, α is included angle between fault trend and maximum horizontal principal stress, and sigmaMMaximum horizontal principal stress in MPa; sigmamIs the minimum horizontal principal stress in MPa,
wherein, in the sealing coefficient IsWhen the fault is more than 1.0, the carbonate rock is in a closed state and has a closing coefficient IsAnd under the condition that the fault is not more than 1.0, the carbonate rock is in an open state.
7. The apparatus of claim 6, wherein the first recovery module for recovering the fluid pressure evolution history of the carbonate reservoir comprises:
observing host minerals and occurrence of inclusion;
acquiring basic parameters of the paleo-pressure, wherein the basic parameters comprise uniform temperature of an oil inclusion and a brine inclusion of the same period, salinity and freezing point temperature of the brine inclusion and gas-liquid ratio of the oil inclusion;
calculating fluid pressures of the carbonate reservoir in different geological historical periods according to the basic parameters by taking the components of the current oil and gas reservoir as initial components;
according to main parameters in the carbonate reservoir fluid pressure simulation, performing the carbonate reservoir fluid pressure simulation to obtain a carbonate reservoir fluid pressure curve, wherein the main parameters comprise: formation age, lithology combination, amount of degradation, history of thermal flux evolution, and rock thermal conductivity; and
and correcting the simulated carbonate reservoir fluid pressure curve by taking the calculated fluid pressures of different geological historical periods as constraint conditions.
8. A machine readable storage medium having stored thereon instructions for enabling a machine to perform a method for evaluating the history of closed evolutionary carbonate fault formations according to any one of claims 1 to 5.
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| CN113051697B (en) * | 2019-12-27 | 2022-10-04 | 中国石油天然气股份有限公司 | Method and device for generating evolution history curve of pore pressure of ancient gas reservoir stratum |
| CN114544918B (en) * | 2020-11-24 | 2024-03-01 | 中国石油天然气股份有限公司 | Method and device for evaluating sealing performance of crude oil pyrolysis gas reservoir |
| CN112780267B (en) * | 2021-02-03 | 2023-02-17 | 中国石油大学(北京) | Method, device and equipment for determining accumulation possibility |
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