CN110259439A - For evaluating the method and device of carbonate rock fault sealing property Evolutionary History - Google Patents
For evaluating the method and device of carbonate rock fault sealing property Evolutionary 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 207
- 239000011435 rock Substances 0.000 title claims abstract description 110
- 238000007789 sealing Methods 0.000 title claims abstract description 67
- 238000000034 method Methods 0.000 title claims abstract description 49
- 239000012530 fluid Substances 0.000 claims abstract description 90
- 238000003325 tomography Methods 0.000 claims abstract description 88
- 230000008569 process Effects 0.000 claims abstract description 15
- 238000009826 distribution Methods 0.000 claims abstract description 13
- 238000011084 recovery Methods 0.000 claims description 21
- 235000002639 sodium chloride Nutrition 0.000 claims description 20
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 19
- 239000011780 sodium chloride Substances 0.000 claims description 19
- 238000004088 simulation Methods 0.000 claims description 14
- 238000010276 construction Methods 0.000 claims description 10
- 230000005484 gravity Effects 0.000 claims description 10
- 238000004364 calculation method Methods 0.000 claims description 9
- 238000003860 storage Methods 0.000 claims description 9
- 230000015572 biosynthetic process Effects 0.000 claims description 7
- 238000007710 freezing Methods 0.000 claims description 6
- 230000008014 freezing Effects 0.000 claims description 6
- 239000007788 liquid Substances 0.000 claims description 6
- 238000012360 testing method Methods 0.000 claims description 6
- 230000001133 acceleration Effects 0.000 claims description 5
- BVKZGUZCCUSVTD-UHFFFAOYSA-N carbonic acid Chemical compound OC(O)=O BVKZGUZCCUSVTD-UHFFFAOYSA-N 0.000 claims description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 5
- 229910052500 inorganic mineral Inorganic materials 0.000 claims description 4
- 235000010755 mineral Nutrition 0.000 claims description 4
- 239000011707 mineral Substances 0.000 claims description 4
- 238000004458 analytical method Methods 0.000 claims description 3
- 238000012937 correction Methods 0.000 claims description 3
- 238000007405 data analysis Methods 0.000 claims description 3
- 238000005553 drilling Methods 0.000 claims description 3
- 230000003628 erosive effect Effects 0.000 claims 2
- 239000004744 fabric Substances 0.000 claims 1
- 239000003208 petroleum Substances 0.000 abstract description 3
- 150000005323 carbonate salts Chemical class 0.000 abstract 1
- 238000010586 diagram Methods 0.000 description 8
- 239000004215 Carbon black (E152) Substances 0.000 description 7
- 229930195733 hydrocarbon Natural products 0.000 description 7
- 150000002430 hydrocarbons Chemical class 0.000 description 7
- 238000011156 evaluation Methods 0.000 description 5
- 238000002591 computed tomography Methods 0.000 description 4
- 238000000265 homogenisation Methods 0.000 description 4
- 238000005259 measurement Methods 0.000 description 4
- 238000004321 preservation Methods 0.000 description 4
- 230000008901 benefit Effects 0.000 description 3
- 230000010429 evolutionary process Effects 0.000 description 3
- 230000005012 migration Effects 0.000 description 3
- 238000013508 migration Methods 0.000 description 3
- 230000008859 change Effects 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- DHNCFAWJNPJGHS-UHFFFAOYSA-J [C+4].[O-]C([O-])=O.[O-]C([O-])=O Chemical compound [C+4].[O-]C([O-])=O.[O-]C([O-])=O DHNCFAWJNPJGHS-UHFFFAOYSA-J 0.000 description 1
- 230000002776 aggregation Effects 0.000 description 1
- 238000004220 aggregation Methods 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 238000004320 controlled atmosphere Methods 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 230000002706 hydrostatic effect Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000035800 maturation Effects 0.000 description 1
- 230000037361 pathway Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000013031 physical testing Methods 0.000 description 1
- 238000011002 quantification Methods 0.000 description 1
- 238000002310 reflectometry Methods 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 230000003068 static effect Effects 0.000 description 1
- 239000004575 stone Substances 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
- 239000004079 vitrinite Substances 0.000 description 1
Classifications
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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]
-
- 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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Abstract
The embodiment of the present invention provides a kind of for evaluating the method and device of carbonate rock fault sealing property Evolutionary History, belongs to petroleum exploration domain.The described method includes: the Pressure Distribution now based on carbonate reservoir, restores the Evolution of fluid pressure history of the carbonate reservoir；Restore the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region；Restore the Evolutionary History of the ancient parameter of the carbonate rock tomography；And the Evolutionary History according to the Evolution of fluid pressure history of the carbonate reservoir, the ancient parameter of the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region, the carbonate rock tomography, the sealing coefficient of the carbonate rock tomography is calculated, to rebuild the carbonate rock fault sealing property Evolutionary History.It can it is easy, accurately and rapidly rebuild carbonate rock fault sealing property Evolutionary History, to disclose and tomography respective carbonate salts oil gas pool Evolution of Oil Reservoiring process.
Description
Technical field
The present invention relates to petroleum exploration domains, and in particular, to one kind is for evaluating the evolution of carbonate rock fault sealing property
The method and device of history.
Background technique
Ancient Deep Carbonate Rocks oil gas field accounts for critical role in China's petroleum resources, wherein carbonic acid related with tomography
Type is wanted based on salt oil gas pool.Tomography plays a significant role in carbonate rock hydrocarbon reservoir, its formation and evolution is not only controlled
The development and evolution of structural trap are made, and there is good transformation effect to deep carbonate reservoirs.In addition, tomography control
The migration and aggregation for making carbonate rock hydrocarbon reservoir oil gas, both can be used as the dominant migration pathway of oil-gas migration, can also make
Oil gas is blocked for lateral obstruction conditions.After hydrocarbon charge, the closure of tomography also controls the preservation of oil-gas reservoir.If oil gas at
Tomography remains static behind hiding and closure is good, then is conducive to the preservation in oil gas later period；On the contrary, later period movable tomography will make
Early stage filling oil-gas escape and can not save.
However, Fault closeness evaluation is confined to the Clastic Stratum of Country Rocks of mudstone creep mostly at present, in carbonate rock tomography
Portion's structure and Seal property research are relatively fewer, and there is presently no the evaluation methods of effective carbonate rock fault sealing property.Together
When, since " fault gouge " that carbonate rock tomographic nuclear is formed is mostly brittleness carbonate rock corrasion as a result, mud stone cannot be used
The sides based on Clastic Stratum of Country Rocks mudstone creep such as the smearing factor (SSF), mudstone creep coefficient (CSP) and fault gouge ratio (SGR)
Method is gone to predict and be evaluated.Therefore, for clear Deep Carbonate Rocks Evolution of Oil Reservoiring process, provide a kind of quantification,
The method of easy accurate evaluation carbonate rock fault sealing property Evolutionary History is a current technical problem urgently to be solved.
Summary of the invention
The purpose of the embodiment of the present invention is that provide a kind of method for evaluating carbonate rock fault sealing property Evolutionary History and
Device, can it is easy, accurately and rapidly rebuild carbonate rock fault sealing property Evolutionary History, to disclose carbonic acid related to tomography
Rock salt oil/gas is at hiding evolutionary process.
To achieve the goals above, the embodiment of the present invention provides a kind of for evaluating carbonate rock fault sealing property Evolutionary History
Method, which comprises the Pressure Distribution now based on carbonate reservoir restores the carbonate reservoir
Evolution of fluid pressure history；According to the construction feature of the carbonate reservoir and structural evolution process, the different periods of history are simulated
Tectonic stress field, to restore the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region；By right
Paleostructure recovery is carried out perpendicular to the section of the carbonate rock fault strike, to obtain the ancient parameter of the carbonate rock tomography
Evolutionary History, wherein the Gu parameter includes palaeoburial depth, the ancient trend of tomography and tendency and ancient inclination angle；And according to
The Evolution of fluid pressure history of the carbonate reservoir, the carbonate reservoir region direct stress size and Orientation
The Evolutionary History of the ancient parameter of Evolutionary History, the carbonate rock tomography calculates the sealing coefficient of the carbonate rock tomography, to rebuild
The carbonate rock fault sealing property Evolutionary History.
Optionally, the Pressure Distribution now of the carbonate reservoir is determined according to following steps: collecting drilling well
Formation pressure test data；And the relationship based on collected data analysis depth-pressure, so that it is determined that the carbonate rock
The Pressure Distribution now of reservoir.
Optionally, the Pressure Distribution now based on carbonate reservoir, restores the carbonate reservoir
Evolution of fluid pressure history includes: to observe host minerals and the occurrence of inclusion enclave；The basic parameter of paleopressure is obtained, it is described basic
Parameter includes oil inclusions and the same period time homogenization temperature of saline inclusion, the salinity of saline inclusion and freezing point temperature, You Bao
Wrap up in the gas liquid ratio of body；It is divided into Initial Composition with oil-gas reservoir group now, according to carbonate reservoir described in the Parameter Calculation
The Fluid pressure of different geology periods of history；According to the major parameter in the simulation of carbonate reservoir Fluid pressure, described in progress
Carbonate reservoir Fluid pressure is simulated to obtain carbonate reservoir fluid pressure profile, wherein the major parameter can wrap
It includes: stratigraphic age, lithology combination, denudation, hot-fluid Evolutionary History and thermal conductivity of rocks；And with different geology calculated
The Fluid pressure of period of history is as constraint condition, to carry out school to the carbonate reservoir fluid pressure profile simulated
Just.
Optionally, the construction feature and structural evolution process according to the carbonate reservoir, simulates different history
The tectonic stress field in period, to restore the Evolutionary History packet of the direct stress size and Orientation of the carbonate reservoir region
It includes: by the analysis of construction feature and tectonic evolution pattern to carbonate reservoir, establishing the geological model of different times；To not
Geological model of the same period carries out the division of finite element；And it is soft using simulating according to the geological model of the different times after division
Part simulates the tectonic stress field of different times, obtains in different geology period of history carbonate reservoir regions
Direct stress size and Orientation, to restore the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region.
Optionally, described by carrying out paleostructure recovery to the section perpendicular to the carbonate rock fault strike, restore
The Evolutionary History at the palaeoburial depth of the carbonate rock tomography, the ancient trend of tomography and tendency and ancient inclination angle includes: that selection is hung down
Directly in the section of the carbonate fault strike, wherein selected section is the section that structural deformation does not occur for one end；It is based on
Tectonic characteristic and structural evolution process determine the detachment layers and fault plane of the section；According to the carbonate reservoir
The tectonic setting of region selects corresponding balance method, carries out compacting or decompaction correction to the carbonate reservoir,
One end of structural deformation does not occur in selected section, selects the straight line vertical with level as staple line；Based on tectonic stress
Environment and tectonic style are come in conjunction with the detachment layers and fault plane, the staple line to selected using corresponding balance model
Section is balanced；After being balanced to selected section, based on the structure section of different geology periods of history, when reading each
The ancient parameter of phase tomography, to restore the Evolutionary History of the ancient parameter of the carbonate rock tomography.
Optionally, the sealing coefficient of the carbonate rock tomography is calculated according to the following formula:
Wherein, IsFor fault sealing coefficient, dimensionless；PwFor Fluid pressure, unit MPa；G is acceleration of gravity, unit
For 9.8m/s2；H is buried depth, unit m；ρrFor the average density in superstratum, unit kg/m3；ρwFor the density of water,
Unit is kg/m3；G is gravity coefficient；θ is co-hade；α is the angle of fault strike and maximum horizontal principal stress；σMFor maximum
Horizontal principal stress, unit MPa；σmFor minimum horizontal principal stress, unit MPa, wherein in sealing coefficient IsFeelings greater than 1.0
Under condition, the carbonate rock tomography is in closed state, in sealing coefficient IsIn the case where 1.0, the carbonate rock
Tomography is in the open state.
Correspondingly, the embodiment of the present invention also provide it is a kind of for evaluating the device of carbonate rock fault sealing property Evolutionary History,
Described device includes: the first recovery module, for the Pressure Distribution now based on carbonate reservoir, restores the carbonic acid
The Evolution of fluid pressure history of rock salt reservoir；Second recovery module, for the construction feature and structure according to the carbonate reservoir
Evolutionary process is made, the tectonic stress field of different periods of history is simulated, to restore just answering for the carbonate reservoir region
The Evolutionary History of power size and Orientation；Third recovery module, for by the section perpendicular to the carbonate rock fault strike
Carry out paleostructure recovery, come obtain the carbonate rock tomography ancient parameter Evolutionary History, wherein it is described Gu parameter buried including Gu
Hide depth, the ancient trend of tomography and tendency and ancient inclination angle；And computing module, for according to the carbonate reservoir
Evolution of fluid pressure history, the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region, the carbonate
The Evolutionary History of the ancient parameter of rock tomography calculates the sealing coefficient of the carbonate rock tomography, to rebuild the carbonate rock tomography
Closure Evolutionary History.
Optionally, the Fluid pressure that first module is used to restore according to following steps the carbonate reservoir is drilled
Changing history includes: to observe host minerals and the occurrence of inclusion enclave；The basic parameter of paleopressure is obtained, the basic parameter includes oil
The gas-liquid of inclusion enclave and the same period time homogenization temperature of saline inclusion, the salinity of saline inclusion and freezing point temperature, oil inclusions
Than；It is divided into Initial Composition with oil-gas reservoir group now, is gone through according to carbonate reservoir difference geology described in the Parameter Calculation
The Fluid pressure in history period；According to the major parameter in the simulation of carbonate reservoir Fluid pressure, the carbonate rock storage is carried out
Layer fluid pressure simulation is to obtain carbonate reservoir fluid pressure profile, wherein the major parameter may include: stratum year
Age, lithology combination, denudation, hot-fluid Evolutionary History and thermal conductivity of rocks；And with the different geology periods of history calculated
Fluid pressure is as constraint condition, to be corrected to the carbonate reservoir fluid pressure profile simulated.
Optionally, the computing module calculates the sealing coefficient of the carbonate rock tomography according to the following formula:
Wherein, IsFor fault sealing coefficient, dimensionless；PwFor Fluid pressure, unit MPa；G is acceleration of gravity, unit
For 9.8m/s2；H is buried depth, unit m；ρrFor the average density in superstratum, unit kg/m3；ρwFor the density of water,
Unit is kg/m3；G is gravity coefficient；θ is co-hade；α is the angle of fault strike and maximum horizontal principal stress；σMFor maximum
Horizontal principal stress, unit MPa；σmFor minimum horizontal principal stress, unit MPa, wherein in sealing coefficient IsFeelings greater than 1.0
Under condition, the carbonate rock tomography is in closed state, in sealing coefficient IsIn the case where 1.0, the carbonate rock
Tomography is in the open state.
Correspondingly, the embodiment of the present invention also provides a kind of machine readable storage medium, on the machine readable storage medium
Be stored with instruction, described instruction be used for so that machine be able to carry out it is above-mentioned for evaluating carbonate rock fault sealing property Evolutionary History
Method.
Through the above technical solutions, restoring different geology by the Evolution of fluid pressure history for restoring carbonate reservoir and going through
The direct stress in history period restores to obtain the ancient parameter of different geology period of history tomographies from paleostructure, is finally based on fossil fluid pressure
Power, direct stress, the tomography Gu parameter computed tomography sealing coefficient of different geology periods of history, quantitative assessment carbonate rock tomography are each
Fault sealing property Evolutionary History so as to simplicity, is accurately and rapidly established in position, each period closure, and announcement has with tomography
The carbonate rock hydrocarbon reservoir oil and gas evolution process of pass.
The other feature and advantage of the embodiment of the present invention will the following detailed description will be given in the detailed implementation section.
Detailed description of the invention
Attached drawing is to further understand for providing to the embodiment of the present invention, and constitute part of specification, under
The specific embodiment in face is used to explain the present invention embodiment together, but does not constitute the limitation to the embodiment of the present invention.Attached
In figure:
Fig. 1 shows according to an embodiment of the invention for evaluating the method for carbonate rock fault sealing property Evolutionary History
Flow diagram；
Fig. 2 shows fluid inclusion pressure recovery result schematic diagrams in an embodiment；
Fig. 3 shows the schematic diagram of the Evolution of fluid pressure history of carbonate reservoir in an embodiment；
Fig. 4 (a) is shown in an embodiment perpendicular to the diagrammatic cross-section of carbonate rock tomography；
Fig. 4 (b) shows the meter of different depth on 4 corresponding control hiding tomography of gas stream well Soviet Union on the Fault profile of Fig. 4 (a)
Calculate the sealing coefficient curve of point；And
Fig. 5 shows according to an embodiment of the invention for evaluating the device of carbonate rock fault sealing property Evolutionary History
Structural block diagram.
Specific embodiment
It is described in detail below in conjunction with specific embodiment of the attached drawing to the embodiment of the present invention.It should be understood that this
Locate described specific embodiment and be merely to illustrate and explain the present invention embodiment, is not intended to restrict the invention embodiment.
Fig. 1 shows according to an embodiment of the invention for evaluating the method for carbonate rock fault sealing property Evolutionary History
Flow diagram.As shown in Figure 1, the embodiment of the present invention provide it is a kind of for evaluating the side of carbonate rock fault sealing property Evolutionary History
Method, the method includes the steps S110 to step S140.
In step S110, the Pressure Distribution now based on carbonate reservoir restores the carbonate reservoir
Evolution of fluid pressure history.
The Evolution of fluid pressure historical example of the carbonate reservoir can such as be indicated when different with curve or similar mode
The Fluid pressure of the carbonate reservoir of phase.
Specifically, the formation pressure test data of drilling well can be collected, collected formation pressure test data may include
Drill-stem test data and formation testing pressure data.Based on the relationship of collected data analysis depth-pressure, thus clear carbon
The Pressure Distribution now of Carbonate Reservoir.
After determining the Pressure Distribution now of carbonate reservoir, fluid inclusion thermokinetics can use
Simulation combination basin modelling method restores carbonate reservoir Evolution of fluid pressure history.It specifically includes following steps, wherein flowing
Body inclusion enclave thermodynamic modeling method is related to the step of being listed below (1)-(3), and basin modelling method is related to the step of being listed below
(4):
(1) to the observation of carbonate reservoir fluid inclusion petrography (host and production including observing inclusion enclave
Shape), tentatively to judge each inclusion enclave formation phase of carbonate reservoir.
(2) basic parameter of paleopressure is obtained, the basic parameter includes oil inclusions and the same period time saline inclusion
The gas liquid ratio of homogenization temperature, the salinity of saline inclusion and freezing point temperature, oil inclusions.Specifically, can be stored up to carbonate rock
The oil inclusions and saline inclusion of the same period time do not carry out micro- thermometric in layer, and the temperature of measurement includes oil inclusions and the same period time
The homogenization temperature of saline inclusion, the salinity of saline inclusion and freezing point temperature.When carrying out thermometric, inclusion temperature sample is chosen
The principle of choosing is individual larger (for example, body volume is greater than certain value), form rule, sharpness of border, because of such package
The destruction being subject to after body capture is minimum, it is believed that is the not changed effective thermometric sample of volume.For different earth histories
The oil inclusions in period obtain the two dimension of oil inclusions by successively scanning using laser confocal scanning microscope (CLSM)
Image recycles software to establish oil inclusions vacation threedimensional model, and then the gas liquid ratio of the not oil inclusions of the same period time is calculated.
(3) Initial Composition is divided into oil-gas reservoir group now, not according to measured Parameter Calculation carbonate reservoir
With the Fluid pressure in earth history period, wherein Fluid pressure now can be obtained by actual measurement.It is real Fig. 2 shows one
Apply fluid inclusion pressure recovery result schematic diagram in example.As shown in Fig. 2, fluid inclusion paleopressure restores mainly to exist
It is obtained on pressure-temperature phasor according to the intersection point of oil inclusions isochor and saline inclusion isochor.Five-pointed star represents in Fig. 2
The intersection point of oil inclusions isochor and saline inclusion isochor, the intersection point are the carbonate rock indicated in the earth history period
Reservoir fluid pressure.Optionally, the Fluid pressure for calculating the different geology periods of history can be simulated by PVTsim software.
(4) according to the major parameter in the simulation of carbonate reservoir Fluid pressure, the carbonate reservoir fluid is carried out
Pressure simulation is to obtain carbonate reservoir fluid pressure profile, wherein the major parameter may include: stratigraphic age, lithology
Combination, denudation, hot-fluid Evolutionary History and thermal conductivity of rocks etc..The Fluid pressure of fluid pressure profile expression different time.It can
Choosing, BasinMod software can be used to carry out the carbonate reservoir Fluid pressure and simulate, in simulation process, be compacted mould
Type can select reciprocal model, and calculation of pressure model can select Bmod fluid model, and porosity calculation can select Bmod2-D
Fluid model, calculation model of permeability can select Power Function model.Analog result can be by surveying Ro (vitrinite
Reflectivity) data, actual measurement porosity data, observed pressure data and the pressure of fluid inclusion paleopressure method calculating
Data are constrained, to guarantee the accuracy of result.It is further alternative, it can be with the fluid of different geology periods of history calculated
Pressure is as constraint condition, to be corrected to the carbonate reservoir fluid pressure profile simulated.
The Evolution of fluid pressure history of carbonate reservoir can be obtained according to above-mentioned step (1)-(4).Fig. 3 shows one
The schematic diagram of the Evolution of fluid pressure history of carbonate reservoir in embodiment, it illustrates the pore pressure of different times and hydrostatic
The change curve of pressure, wherein abscissa indicates that different times, ordinate indicate Fluid pressure.Pore pressure shown in Fig. 3
Change curve is the Evolution of fluid pressure history of carbonate reservoir, and wherein five-pointed star indicates the paleopressure that inclusion enclave restores,
Namely the Fluid pressure of the different geology periods of history calculated in step (4).The five-pointed star of the rightmost side is actual measurement now in figure
Fluid pressure.
Different history are simulated according to the construction feature of the carbonate reservoir and structural evolution process in step S120
The tectonic stress field in period, to restore the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region.
The Evolutionary History of the direct stress size and Orientation can for example be indicated with curve or similar mode it is described differently
The direct stress size and Orientation of carbonate reservoir region described in the matter period of history.Step S120 can specifically include following
Step:
(1) by the analysis of construction feature and Evolution of fluid pressure history to carbonate reservoir, different times are established
Geological model；
(2) division that finite element is carried out to the geological model of different times assigns mould by physical testing and well-log information
The reasonable rock mechanics parameters of type, and it is subject to reasonable load, constraint and boundary condition；
(3) according to the geological model of the different times after division using simulation softward to the tectonic stress fields of different times into
Row simulation, to obtain the direct stress size and Orientation in different geology period of history carbonate reservoir regions, to restore
The Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region.
In step S130, by carrying out paleostructure recovery to the section perpendicular to the carbonate rock fault strike, to obtain
The Evolutionary History of the ancient parameter of the carbonate rock tomography is taken, the Gu parameter may include the ancient trend of palaeoburial depth, tomography
With tendency and ancient inclination angle.
The Evolutionary History of ancient parameter can indicate the ancient parameter of the tomography of different times with curve or similar mode.Step S130
It can specifically include following steps:
(1) section perpendicular to the carbonate fault strike is selected.Structure does not preferably occur for one end of selected section
Deformation is made, in favor of determining staple line when balance.
(2) it is based on tectonic characteristic and structural evolution process, determines the detachment layers and fault plane of the section.
(3) according to the tectonic setting of the carbonate reservoir region, corresponding balance method is selected, to the carbon
Carbonate Reservoir carries out compacting or decompaction correction, and one end of structural deformation, selection and level do not occur in selected section
Vertical straight line is as staple line.
(4) it is based on tectonic stress environment and tectonic style, using corresponding balance model, in conjunction with the detachment layers and tomography
Face, the staple line are balanced selected section.
(5) after being balanced to selected section, based on the structure section of different geology periods of history, each period is read
The ancient parameter of tomography, to restore the Evolutionary History of the ancient parameter of carbonate rock tomography.
In step S140, according to where the Evolution of fluid pressure history of the carbonate reservoir, the carbonate reservoir
The Evolutionary History of the direct stress size and Orientation in region, the palaeoburial depth of the carbonate rock tomography, the ancient of tomography move towards and incline
To and ancient inclination angle Evolutionary History, the Evolutionary History of the sealing coefficient of the carbonate rock tomography is calculated, to rebuild the carbonate
Rock fault sealing property Evolutionary History.
Pressure recovery is answered based on Gu as a result, in conjunction with tomography palaeoburial depth, the ancient trend of tomography and tendency, ancient dip angle parameter
And the sealing coefficient of reservoir paleopressure result computed tomography, different geology period of history fault sealing properties are determined, with weight
Build carbonate rock fault sealing property Evolutionary History.It can specifically include following steps:
(1) Fluid pressure has decisive role to the unlatching of tomography, i.e., when shear-zone fluid pressure is greater than or equal to
Fault opening when section direct stress, the fault sealing when shear-zone fluid pressure is less than or equal to section direct stress.Then it can be used
Fault sealing coefficient IsThe closure of tomography is evaluated, is defined as the ratio of direct stress and Fluid pressure suffered by fault plane, is sealed
Close coefficient IsCalculation formula it is as follows:
In formula: IsFor fault sealing coefficient, dimensionless；σ is direct stress, unit MPa；PwFor Fluid pressure, unit is
MPa；G is acceleration of gravity, unit 9.8m/s2；H is buried depth, unit m；ρrIt is single for the average density in superstratum
Position is kg/m3；ρwFor the density of water, unit kg/m3；G is gravity coefficient；θ is co-hade；α is fault strike and most flood
The angle of flat principal stress；σMFor maximum horizontal principal stress, unit MPa；σmFor minimum horizontal principal stress, unit MPa.
If sealing coefficient IsGreater than 1.0, tomography is in closed state and is conducive to the preservation after hydrocarbon charge；If sealing coefficient
IsWhen less than 1.0, tomography is in the open state, the tomography loss opened along the later period of oil gas after Pool-forming time filling and can not protect
It deposits.
(2) based on research Qu Guying pressure recovery result, tomography Gu parameter and reservoir paleopressure result according to public affairs
The sealing coefficient I of formula (1) computed tomographys, determine that carbonate rock tomography in different geology period of history closure, rebuilds tomography envelope
Closing property Evolutionary History.
Fig. 4 (a) is shown in an embodiment perpendicular to the diagrammatic cross-section of carbonate rock tomography.Fig. 4 (b) shows Fig. 4
(a) the sealing coefficient curve of the calculating point of different depth on tomography is hidden in the corresponding control of gas stream well Soviet Union 4 on Fault profile.Fig. 4
(b) in, the sealing coefficient of the calculating point (point 1 and point 2) of different depth is differently on 4 corresponding control hiding tomography of gas stream well Soviet Union
The matter period of history, (30Ma-0Ma) was all larger than 1.0, showed that control hiding tomography is constantly in closed state after hydrocarbon charge, to oil
Gas reservoir plays the role of good preservation.
The execution sequence of above-mentioned steps S110, step S120 and step S130 can be arbitrary, and the embodiment of the present invention is simultaneously
It is not limited.Specific implementation step according to an embodiment of the present invention, can be to same carbonate rock tomography different parts, difference
Period carries out closure and carries out quantitative assessment, to establish, oil-gas reservoir interior oil controlled atmosphere is whole, evolutionary process.
Fig. 5 shows according to an embodiment of the invention for evaluating the device of carbonate rock fault sealing property Evolutionary History
Structural block diagram.As shown in figure 5, the embodiment of the present invention also provide it is a kind of for evaluating the dress of carbonate rock fault sealing property Evolutionary History
It sets, the apparatus may include: the first recovery module 510 is restored for the Pressure Distribution now based on carbonate reservoir
The Evolution of fluid pressure history of the carbonate reservoir；Second recovery module 520, for the structure according to the carbonate reservoir
Feature and structural evolution process are made, the tectonic stress field of different periods of history is simulated, to restore the carbonate reservoir place
The Evolutionary History of the direct stress size and Orientation in region；Third recovery module 530, for by disconnected perpendicular to the carbonate rock
Layer trend section carry out paleostructure recovery, come obtain the carbonate rock tomography ancient parameter Evolutionary History, wherein the Gu
Parameter includes palaeoburial depth, the ancient trend of tomography and tendency and ancient inclination angle；And computing module 540, for according to
The Evolution of fluid pressure history of carbonate reservoir, the carbonate reservoir region direct stress size and Orientation evolution
The Evolutionary History of history, the ancient parameter of the carbonate rock tomography, calculates the sealing coefficient of the carbonate rock tomography, described in rebuilding
Carbonate rock fault sealing property Evolutionary History.
Specific works provided in an embodiment of the present invention for evaluating the device of carbonate rock fault sealing property Evolutionary History are former
The method for being used to evaluate carbonate rock fault sealing property Evolutionary History that reason and benefit and the embodiments of the present invention provide it is specific
Working principle and benefit are similar, will not be described in great detail here.
Correspondingly, the embodiment of the present invention also provides a kind of machine readable storage medium, on the machine readable storage medium
It is stored with instruction, described instruction is used for so that machine is able to carry out described in any embodiment according to the present invention for evaluating carbonic acid
The method of rock salt fault sealing property Evolutionary History.
The embodiment of the present invention is based on paleotectonic stress field, paleopressure, tomography Gu occurrence computed tomography sealing coefficient, fixed
Each position of amount evaluation carbonate rock tomography, each period closure, to establish fault sealing property Evolutionary History, and announcement has with tomography
The carbonate rock hydrocarbon reservoir oil and gas evolution process of pass.
Carbonate rock tomography of the scheme provided in an embodiment of the present invention suitable for no fault plane mudstone creep, not by more phase structures
The limitation for making evolution background, fluid dynamic complexity, is not only suitable for early stage exploration areas, is also applied for opening for advanced stage exploration maturation
Send out area, provide effective reliable new way for the evaluation of ancient Deep Carbonate Rocks fault sealing property Evolutionary History, thus guidance and
The relevant Deep Carbonate Rocks oil exploration and exploitation of tomography.
The optional embodiment of the embodiment of the present invention is described in detail in conjunction with attached drawing above, still, the embodiment of the present invention is simultaneously
The detail being not limited in above embodiment can be to of the invention real in the range of the technology design of the embodiment of the present invention
The technical solution for applying example carries out a variety of simple variants, these simple variants belong to the protection scope of the embodiment of the present invention.
It is further to note that specific technical features described in the above specific embodiments, in not lance
In the case where shield, it can be combined in any appropriate way.In order to avoid unnecessary repetition, the embodiment of the present invention pair
No further explanation will be given for various combinations of possible ways.
It will be appreciated by those skilled in the art that implementing the method for the above embodiments is that can pass through
Program is completed to instruct relevant hardware, which is stored in a storage medium, including some instructions are used so that single
Piece machine, chip or processor (processor) execute all or part of the steps of each embodiment the method for the application.And it is preceding
The storage medium stated includes: USB flash disk, mobile hard disk, read-only memory (ROM, Read-Only Memory), random access memory
The various media that can store program code such as (RAM, Random Access Memory), magnetic or disk.
In addition, any combination can also be carried out between a variety of different embodiments of the embodiment of the present invention, as long as it is not
The thought of the embodiment of the present invention is violated, equally should be considered as disclosure of that of the embodiment of the present invention.
Claims (10)
1. a kind of method for evaluating carbonate rock fault sealing property Evolutionary History, which is characterized in that the described method includes:
Pressure Distribution now based on carbonate reservoir restores the Evolution of fluid pressure history of the carbonate reservoir；
According to the construction feature of the carbonate reservoir and structural evolution process, the tectonic stress of different periods of history is simulated
, to restore the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region；
It is disconnected to obtain the carbonate rock by carrying out paleostructure recovery to the section perpendicular to the carbonate rock fault strike
The Evolutionary History of the ancient parameter of layer, wherein the Gu parameter includes that palaeoburial depth, the ancient trend of tomography and tendency and Gu incline
Angle；And
According to the Evolution of fluid pressure history of the carbonate reservoir, the direct stress size of the carbonate reservoir region
With the Evolutionary History of the Evolutionary History in direction, the ancient parameter of the carbonate rock tomography, the closing system of the carbonate rock tomography is calculated
Number, to rebuild the carbonate rock fault sealing property Evolutionary History.
2. the method according to claim 1, wherein determining showing for the carbonate reservoir according to following steps
Modern Pressure Distribution:
Collect the formation pressure test data of drilling well；And
Based on the relationship of collected data analysis depth-pressure, so that it is determined that the pressure now of the carbonate reservoir point
Cloth feature.
3. the method according to claim 1, wherein the pressure now based on carbonate reservoir is distributed spy
Sign, the Evolution of fluid pressure history for restoring the carbonate reservoir include:
Observe host minerals and the occurrence of inclusion enclave；
The basic parameter of paleopressure is obtained, the basic parameter includes the uniform temperature of oil inclusions and the same period time saline inclusion
The gas liquid ratio of degree, the salinity of saline inclusion and freezing point temperature, oil inclusions；
It is divided into Initial Composition with oil-gas reservoir group now, is gone through according to carbonate reservoir difference geology described in the Parameter Calculation
The Fluid pressure in history period；
According to the major parameter in the simulation of carbonate reservoir Fluid pressure, the carbonate reservoir Fluid pressure simulation is carried out
To obtain carbonate reservoir fluid pressure profile, wherein the major parameter may include: stratigraphic age, lithology combination, stripping
Erosion amount, hot-fluid Evolutionary History and thermal conductivity of rocks；And
Using the Fluid pressure of different geology periods of history calculated as constraint condition, to be stored up to the carbonate rock simulated
Layer fluid pressure curve is corrected.
4. the method according to claim 1, wherein the construction feature according to the carbonate reservoir and
Structural evolution process simulates the tectonic stress field of different periods of history, to restore the carbonate reservoir region just
Stress intensity and the Evolutionary History in direction include:
By the analysis of construction feature and tectonic evolution pattern to carbonate reservoir, the geological model of different times is established；
The division of finite element is carried out to the geological model of different times；And
It is simulated according to the geological model of the different times after division using tectonic stress field of the simulation softward to different times,
The direct stress size and Orientation in different geology period of history carbonate reservoir regions is obtained, to restore the carbonate
The Evolutionary History of the direct stress size and Orientation of rock reservoir region.
5. the method according to claim 1, wherein described by perpendicular to the carbonate rock fault strike
Section carry out paleostructure recovery, restore the palaeoburial depth of the carbonate rock tomography, the ancient trend of tomography and tendency and
The Evolutionary History at ancient inclination angle includes:
The section perpendicular to the carbonate fault strike is selected, wherein selected section is that structural deformation does not occur for one end
Section；
Based on tectonic characteristic and structural evolution process, the detachment layers and fault plane of the section are determined；
According to the tectonic setting of the carbonate reservoir region, corresponding balance method is selected, to the carbonate rock
Reservoir carries out compacting or decompaction correction, and one end of structural deformation does not occur in selected section, selects vertical with level
Straight line is as staple line；
Based on tectonic stress environment and tectonic style, using corresponding balance model, in conjunction with the detachment layers and fault plane, described
Staple line is balanced selected section；
After being balanced to selected section, based on the structure section of different geology periods of history, each period tomography is read
Ancient parameter, to restore the Evolutionary History of the ancient parameter of the carbonate rock tomography.
6. the method according to claim 1, wherein calculating the envelope of the carbonate rock tomography according to the following formula
Close coefficient:
Wherein, IsFor fault sealing coefficient, dimensionless；PwFor Fluid pressure, unit MPa；G is acceleration of gravity, and unit is
9.8m/s2；H is buried depth, unit m；ρrFor the average density in superstratum, unit kg/m3；ρwIt is single for the density of water
Position is kg/m3；G is gravity coefficient；θ is co-hade；α is the angle of fault strike and maximum horizontal principal stress；σMFor most flood
Flat principal stress, unit MPa；σmFor minimum horizontal principal stress, unit MPa,
Wherein, in sealing coefficient IsIn the case where 1.0, the carbonate rock tomography is in closed state, in sealing coefficient Is
In the case where 1.0, the carbonate rock tomography is in the open state.
7. a kind of for evaluating the device of carbonate rock fault sealing property Evolutionary History, which is characterized in that described device includes:
First recovery module restores the carbonate reservoir for the Pressure Distribution now based on carbonate reservoir
Evolution of fluid pressure history；
Second recovery module is simulated difference and is gone through for the construction feature and structural evolution process according to the carbonate reservoir
The tectonic stress field in history period, to restore the Evolutionary History of the direct stress size and Orientation of the carbonate reservoir region；
Third recovery module, for coming by carrying out paleostructure recovery to the section perpendicular to the carbonate rock fault strike
Obtain the Evolutionary History of the ancient parameter of the carbonate rock tomography, wherein it is described Gu parameter include palaeoburial depth, tomography Gu walk
To with tendency and ancient inclination angle；And
Computing module, for the Evolution of fluid pressure history according to the carbonate reservoir, the carbonate reservoir location
The Evolutionary History of the ancient parameter of the Evolutionary History of the direct stress size and Orientation in domain, the carbonate rock tomography, calculates the carbonate
The sealing coefficient of rock tomography, to rebuild the carbonate rock fault sealing property Evolutionary History.
8. device according to claim 7, which is characterized in that first module is used for according to following steps to restore
The Evolution of fluid pressure history for stating carbonate reservoir includes:
Observe host minerals and the occurrence of inclusion enclave；
The basic parameter of paleopressure is obtained, the basic parameter includes the uniform temperature of oil inclusions and the same period time saline inclusion
The gas liquid ratio of degree, the salinity of saline inclusion and freezing point temperature, oil inclusions；
It is divided into Initial Composition with oil-gas reservoir group now, is gone through according to carbonate reservoir difference geology described in the Parameter Calculation
The Fluid pressure in history period；
According to the major parameter in the simulation of carbonate reservoir Fluid pressure, the carbonate reservoir Fluid pressure simulation is carried out
To obtain carbonate reservoir fluid pressure profile, wherein the major parameter may include: stratigraphic age, lithology combination, stripping
Erosion amount, hot-fluid Evolutionary History and thermal conductivity of rocks；And
Using the Fluid pressure of different geology periods of history calculated as constraint condition, to be stored up to the carbonate rock simulated
Layer fluid pressure curve is corrected.
9. device according to claim 7, which is characterized in that the computing module calculates the carbonic acid according to the following formula
The sealing coefficient of rock salt tomography:
Wherein, IsFor fault sealing coefficient, dimensionless；PwFor Fluid pressure, unit MPa；G is acceleration of gravity, and unit is
9.8m/s2；H is buried depth, unit m；ρrFor the average density in superstratum, unit kg/m3；ρwIt is single for the density of water
Position is kg/m3；G is gravity coefficient；θ is co-hade；α is the angle of fault strike and maximum horizontal principal stress；σMFor most flood
Flat principal stress, unit MPa；σmFor minimum horizontal principal stress, unit MPa,
Wherein, in sealing coefficient IsIn the case where 1.0, the carbonate rock tomography is in closed state, in sealing coefficient Is
In the case where 1.0, the carbonate rock tomography is in the open state.
10. a kind of machine readable storage medium, which is characterized in that instruction is stored on the machine readable storage medium, it is described
Instruction be used for so that machine be able to carry out it is according to any one of claim 1 to 5 for evaluate carbonate rock tomography envelope
The method of closing property Evolutionary History.
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