CN109993461B - Quantitative evaluation method for oil-gas longitudinal flow-dividing proportion under condition of cover-breaking configuration - Google Patents
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Abstract
The invention relates to the technical field of oil-gas exploration, and provides a quantitative evaluation method of oil-gas longitudinal flow-dividing proportion under a fracture-cover configuration condition; the method is characterized in that parameters for evaluating the configuration relationship of the fracture-cover (fault and cover layer) are set from two angles of migration and storage respectively according to the four aspects of macroscopicity, microcosmicity, space and time, and on the basis of determining the oil gas enrichment degrees of different layers of wells, the mathematical relationship between the parameters and the longitudinal oil gas flow distribution ratio of the upper oil gas flow distribution ratio and the lower oil gas flow distribution ratio of the cover layer is determined, so that the control effect of the fracture-cover configuration on the longitudinal oil gas flow distribution is determined. The method is suitable for the research area of multilayer oil-gas-containing. Under the condition that reservoir formation factors such as oil gas filling conditions, reservoir conditions and the like are basically consistent in development, the longitudinal shunting effect of the cap-breaking configuration on oil gas is determined according to quantitative evaluation of the cap-breaking configuration relation, and the method has important significance on deployment of oil gas longitudinal exploration layer series.
Description
Technical Field
The invention relates to the technical field of oil-gas exploration, in particular to a quantitative evaluation method for oil-gas longitudinal diversion ratio under a fault-cover (fault and cover layer) configuration condition.
Background
Oil gas exploration practices show that the cover layer can effectively seal oil gas on the region only when the cover layer is distributed continuously in space, so that the oil gas is gathered into a reservoir in a large scale; otherwise, the oil gas is not beneficial to be gathered into reserves on a large scale. Whether the cover layer is continuous in space or not is related to the development characteristics of the cover layer, and the larger the thickness is, the better the continuity of the spatial distribution of the cover layer is; otherwise, the worse. But whether the cover layer is continuous in spatial distribution or not depends on the reconstruction and destruction effects of fracture at the later stage, if the fracture distance of the fracture is smaller than the thickness of the cover layer, the fracture does not completely stagger the cover layer, the continuity of the cover layer is still maintained in the spatial distribution, and the method is effective for oil gas accumulation and storage. Conversely, if the fracture pitch is greater than the thickness of the cover layer, the fracture completely breaks the cover layer, and the cover layer appears "skylights" with a discontinuous spatial distribution. The oil gas is dissipated outwards from the skylight, which is not beneficial to the accumulation and storage of the oil gas. Therefore, the configuration relationship of the broken cover plays an important role in whether the cover layer can cover oil and gas.
The current methods for configuring the break-cover mainly comprise a breaking and connecting thickness method, an effective breaking and connecting thickness method, an SGR lower limit method, a plate method, a CSI index method and the like.
(1) Breaking thickness method, effective breaking thickness method (luyan fang, 2008):
H＝HcoverFormula (i)
H'＝(HCover-h) cos θ equation @
Wherein H represents the breaking thickness in m; hCover-cap layer thickness, in m; h-fault vertical fault distance, unit m; h' -breaking thickness, unit m; theta-fault dip, unit deg..
The method has the advantages that the damage degree of the cover layer by the fault can be visually reflected, and the parameters are easy to obtain; the method has the defects that only qualitative or semi-quantitative representation is adopted, how to determine the lower limit of the breaking-connecting thickness is considered, the evaluation factors are one-sided, evaluation is only performed on the continuity of the cover layer, the microscopic effect, the time effectiveness and other aspects are not related, the evaluation mechanism is incomplete, and the control effect of the breaking-covering configuration on the longitudinal oil-gas flow splitting cannot be represented.
(2) SGR lower limit method (Swingin, 2017)
From the microscopic angle of effectiveness of the fracture-cover configuration, the fracture-cover configuration mainly depends on the relative size of the fault rock and the reservoir displacement pressure, and when the fracture rock displacement pressure of the fracture overburden is greater than the pressure of the underlying reservoir, the fracture-cover configuration is better, and oil and gas can be effectively sealed. The former proposes the concept of "SGR lower limit of the effective of the open-lid configuration", and can perform calculation by formula c. And when the SGR value of the fault rock is greater than the SGR lower limit, the fault-cover configuration is considered to be effective, and the oil gas can be covered.
In the formula, SGRlim-fault rock SGR lower limit of effectiveness of the break-cover configuration;
Vsh store-reservoir shale percentage,%; t isBreak-offThe action time of the fault rock compaction diagenesis in unit Ma;
TgroundCompacting diagenesis action time of the fault rock surrounding rock in unit Ma; rhorOverburden density in g/cm3；
ρwDensity of formation water in g/cm3(ii) a Theta is the fracture dip in units.
The method is from a microscopic perspective, and from the essence of the effectiveness of the cover-break configuration, the evaluation mechanism is more reliable. The method has the defects that the consideration factors are incomplete and are only considered from a microscopic view, but the reverse side of macroscopic distribution, time effectiveness and the like is not designed, the evaluation mechanism is incomplete, and the control effect of the cover-breaking configuration on the longitudinal oil-gas flow splitting cannot be represented.
(3) The layout method (pay dawn fly, 2015):
and (3) establishing a natural gas storage condition quantitative determination diagram by integrating 4 factors of the brittleness and the plasticity of the gypsum-salt rock, the critical breaking and connecting thickness, the critical SSF value and the minimum connecting amplitude.
The method is considered in aspects of macro, micro, time and the like, and compared with various existing evaluation methods, the method has comprehensive consideration factors. The method has the defects that the method for establishing the plate is only semi-quantitative representation, the relation of the broken-cover configuration is not quantitatively represented, and the method can only evaluate whether the oil gas under the broken-cover configuration can be accumulated or not, but cannot represent the vertical oil gas flow-splitting ratio under the broken-cover configuration.
(4) CSI indexing method (Shijijian, 2011)
The historical construction (2011) defines a comprehensive quantitative evaluation index CSI (Cap Seal index) of the cap layer sealing capability according to the relation between each main parameter influencing the cap layer sealing capability and lists a calculation formula, such as a formula
When H is presentCoverWhen not less than L, HIs effective＝HCover-L
When H is presentCover< L, and pBreak-off≥pStore upWhen H is presentIs effective＝HCover
When H is presentCover< L, and pBreak-off＜pStore upWhen H is presentIs effective＝0
In the formula, the CSI-gas reservoir cover layer sealing capability comprehensive quantitative evaluation index; pmin-minimum cap segment displacement pressure in MPa; po-excluding the normalized standard value of pressure in MPa; k is the gas reservoir pressure coefficient; k is a radical ofo-gas reservoir pressure coefficient normalization standard value; h-cap thickness, unit m; h-vertical fault throw, unit m.
The method evaluates the cap-breaking configuration from two aspects of time and space, and carries out classification discussion on different conditions, and the method is feasible and relatively complete. The defects are that the brittleness, the plasticity and the like of the cover layer are not considered, and the control effect of the cover-breaking configuration on the oil-gas longitudinal flow distribution cannot be represented.
In summary, the following steps: these methods all characterize the effectiveness of the break-cover configuration qualitatively or semi-quantitatively, but take fewer and less comprehensive considerations.
The invention comprehensively and quantitatively evaluates the essence of the effectiveness of the fracture-cover configuration from four angles of macroscopicity, microcosmicity, space and time by aiming at the effectiveness of the fracture-cover configuration relationship and combining the enrichment degree of oil gas, and finally establishes the mathematical relationship between each parameter of the fracture-cover configuration and the enrichment degree of the oil gas so as to determine the oil gas diversion ratio of the fracture-cover configuration to the upper reservoir layer and the lower reservoir layer of the cover layer, predict the oil gas enrichment layer series and guide the deployment of the oil gas favorable exploration layer series and zone.
Disclosure of Invention
(1) The invention principle is as follows:
the invention discloses a quantitative evaluation method for oil-gas longitudinal flow-dividing proportion under a broken-cover configuration condition. The method sets and evaluates each parameter of the configuration relation of the fracture-cover (fault and cover layer) from two angles of migration and storage respectively according to four aspects of macroscopicity, microcosmicity, space and time, determines the mathematical relation between each parameter and the longitudinal oil-gas flow-splitting ratio of the upper oil-gas flow-splitting ratio and the lower oil-gas flow-splitting ratio of the cover layer on the basis of determining the oil-gas enrichment degree of different layers of wells, and further determines the control effect of the fracture-cover configuration on the longitudinal oil-gas flow-splitting. The method is suitable for the research area of multilayer oil-gas-containing. Under the condition that reservoir formation factors such as oil gas filling conditions, reservoir conditions and the like are basically consistent in development, the longitudinal shunting effect of the cover-breaking configuration on oil gas is determined according to quantitative evaluation of the cover-breaking configuration relation. In order to eliminate the influence of hydrocarbon source rocks on the oil-gas enrichment degree, the ratio of the oil-gas enrichment degrees above and below the cover layer is selected as a dependent variable in the evaluation, namely the longitudinal oil-gas diversion ratio of the cover-breaking configuration is set as a dependent variable Y, and the molecule is the oil-gas enrichment degree R above the cover layera onThe denominator is the oil-gas enrichment degree R under the cover layera is underAs in equation (1). Similarly, the independent variable X is also in a ratio mode, wherein the numerator is a parameter representing the migration condition, and the denominator is a corresponding parameter representing the storage condition, as shown in formula (2).
In the formula, Fm is a migration coefficient; fp is a storage coefficient; i is the number of the argument.
The cap-break coupling occlusion control effect can be evaluated from two angles, one on different scales and one on different dimensions. Wherein, the scale comprises macro and micro, and the dimension comprises time and space. Combining the research results of the fracture-cover space-time effectiveness evaluation, four independent variables X including a microscopic evaluation variable X are selected in the evaluation1Macroscopic evaluation variable X2Space evaluation variable X3Time evaluation variable X4。
Wherein, the variable X1The characteristic of the break-cover coupling is evaluated from the view point of microscopic displacement pressure, namely the reservoir displacement pressure (P) adjacent to the cover layerr) Pressure (P) of displacement with fault rockf) The ratio (as the formula (3)) represents the migration resistance, and the larger the value is, the higher the probability that the oil gas migrates upwards is indicated; variable X2Evaluated from a macroscopic perspective, the distance of interruption (H)f) And the thickness (H) of the cap layerc) Characterizing the continuity of the cap layer (as in equation (4)); variable X3Starting from space availability, SGR lower bound (SGR)llim) The larger the value is, the more favorable the upward migration of the oil gas is, and the larger the SGR value is, the more favorable the oil gas preservation is, so the value is set as the ratio of the SGR lower limit to the SGR (as in the formula (5)); variable X4And (3) taking the fault activity time and the matching relation between the cover layer brittleness-plasticity conversion time and the storage period into consideration, and evaluating the control effect of the cover breakage coupling characteristic on oil and gas migration and accumulation from the time effectiveness perspective. Meanwhile, the fracture dip angle theta has a flow splitting effect on oil and gas, so that quantitative evaluation also takes the oil and gas into consideration. Other methods of calculating the parameters are described in detail above, with the focus on variable X4The computing idea and the computing method are explained in detail. Firstly, the methodFor the fault, the time for effectively and vertically transporting oil gas in large scale is the time for fault activity when the oil gas is accumulated, and the time for transporting the oil gas in the fault activity period and the static period is given as 9:1 in consideration of the larger difference of the oil gas transportation efficiency, so that the variable X is set as4The expression of the migration coefficient of (c) is shown in equation (6). For the cover layer, the mechanical property of the cover layer has important influence on the storage condition of the cover layer, the cover layer in the research area does not reach the plastic deformation stage in the oil-gas accumulation period, so that only the time proportion of brittle deformation and brittle-plastic deformation in the accumulation period is assigned, the weight coefficients are set to be 0.3 and 0.7 respectively according to the influence of the mechanical property of the cover layer on the quality of the cover layer, and the variable X is set to be 0.34The storage coefficient expression of (2) is shown in formula (7). Finally, the variable X is calculated according to equation (8)4The numerical value of (c).
Fm4＝0.9×Ta/T+0.1×Ts/T (6)
Fp4＝0.3×Tb/T+0.7×Tb-p/T (7)
In the formula, Pr-reservoir drainage pressure, in MPa; pf-fault rock displacement pressure, in MPa; hf-fault throw, in m; hc-cap layer thickness, in m; SGRllim-SGR lower bound on the effectiveness of the open-lid configuration; SGR-offA mudstone smearing rate of the bed mudstone; t-the oil and gas reservoir formation time of the first phase of the research area is 4.8Ma, the oil and gas reservoir formation time span of the second phase of the research area is 13Ma, and the total is 17.8 Ma; t isa-fault activity time, in Ma; t issFault rest time, in Ma; t isb-cap layer brittle deformation time, in Ma; t isb-pCap brittleness-plastic deformation time, unit Ma.
And on the premise that the total weight value is set to be 1, carrying out weight assignment on each evaluation index in consideration of the importance degree of each variable on oil-gas longitudinal flow splitting. On the basis, the fracture dip angle is considered, the quantity relation between the oil-gas longitudinal flow distribution proportion Y value and each variable is established, and the control effect of the cover-breaking configuration on the oil-gas longitudinal flow distribution is determined.
(2) The invention comprises the following steps:
the invention aims to provide a quantitative evaluation method of oil-gas longitudinal flow-dividing proportion under the condition of a broken-cover configuration, aiming at the defects and shortcomings of the prior art, and the method comprises the following specific steps:
(1) determining a research area, selecting an evaluation layer position of a broken-cover configuration, and selecting N measuring points;
(2) microscopic angle evaluation: preferably selecting samples of each measuring point, testing the reservoir displacement pressure and the fault rock displacement pressure of each measuring point, and calculating the variable X according to the formula (3)1；
(3) And (3) macroscopic angle evaluation: calculating fault distance and cover layer thickness of each measuring point by using single well logging, layering and three-dimensional seismic data, and calculating variable X according to formula (4)2；
(4) And (3) evaluating a space angle: reading related data, calculating the SGR value of the fault rock of each measuring point according to a formula (9), and calculating the SGR by using a formula (10)llimCalculating the variable X according to equation (5)3；
In the formula, SGRllim-SGR lower limit value of the effectiveness of the open-lid configuration; t isBreak-offTime of onset of diagenesis of fault rock, in Ma; t isStore upCompacting diagenesis action time of the fault rock surrounding rock in unit Ma; rhorOverburden density in g/cm3；ρwIs the density of the water of the stratum in g/cm3(ii) a Theta-angle of fracture in degrees;
(5) evaluation of time angle: determining the oil and gas accumulation time T and the period according to inclusion experiment tests; determining the time of flight T of a fault from seismic dataaAnd rest time Ts(ii) a According to the triaxial compression test, determining the brittle plasticity of the cover layer in the geological history period, thereby determining the brittle deformation time T of the cover layerbBrittle plastic deformation time T of cap layerb-p. The variable X is calculated according to the equations (6), (7) and (8)4；
(6) Acquiring a fault dip angle: reading related data according to the three-dimensional seismic data, and determining a fault dip angle;
(7) calculating the longitudinal flow-dividing proportion of the oil gas on the target cover layer and the oil gas on the target cover layer of each well: the method comprises the steps of utilizing logging, well logging and oil testing data of a single well, utilizing a formula (11) to calculate the oil gas enrichment degree R above the cover layer on the basis of determining the value assignment, the corresponding thickness and the sandstone thickness of each oil gas display grade of different dataaDegree of oil and gas enrichment R above and below the cap layeraThe method is disclosed in the invention patent application of Chinese invention patent No. 201811108390.9, and is not described in detail herein; then, respectively calculating the ratio of the oil gas accumulation effective values above and below the cover layer of the well where the measuring point is located by using the formula (1), thereby obtaining a dependent variable Y;
(8) fitting formula: counting the migration coefficient and the storage coefficient of each parameter of the broken-cover configuration, and calculating to obtain the numerical value of each variable; according to four independent variables X1，X2，X3，X4Setting the assignment of each variable, wherein the angle evaluation variable of the microscopic displacement pressure is 0.4, the macroscopic angle evaluation variable is 0.2, the space effectiveness evaluation variable is 0.3, and the time effectiveness evaluation variable is 0.4The variable is 0.1; calculating and summing products of the numerical values of the respective variables and corresponding weights, and establishing a quantitative relation between the products and the longitudinal oil-gas flow splitting ratio and the fracture dip angle; through regression statistics of parameters, on the basis of weight assignment of each variable, a mathematical relation between independent variables and dependent variables is established by combining fault dip angles, and the mathematical relation is used for quantitative evaluation of oil-gas longitudinal flow splitting ratio under the condition of cover-breaking configuration.
The invention has the beneficial effects that: the invention relates to a quantitative evaluation method of oil-gas longitudinal flow-dividing proportion under the condition of cut-cover configuration, which sets and evaluates each parameter of cut-cover (fault and cover layer) configuration relation from two angles of migration and storage respectively according to four aspects of macroscopicity, microcosmic, space and time, determines the mathematical relation of each parameter and the oil-gas longitudinal flow-dividing proportion on and under the cover layer on the basis of determining the oil-gas enrichment degree of different layers of wells, and further determines the control effect of cut-cover configuration on oil-gas longitudinal flow-dividing. The method is suitable for the research area of multilayer oil-gas-containing. Under the condition that reservoir formation factors such as oil gas filling conditions, reservoir conditions and the like are basically consistent in development, the longitudinal shunting effect of the cap-breaking configuration on oil gas is determined according to quantitative evaluation of the cap-breaking configuration relation, and the method has important significance on deployment of oil gas longitudinal exploration layer series.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this application, illustrate embodiment(s) of the invention and together with the description serve to explain the principles of the invention:
FIG. 1 is a technical route diagram of a quantitative evaluation method of oil-gas longitudinal split ratio under a cap-breaking configuration condition;
FIG. 2 is a relation between oil-gas longitudinal flow-splitting ratio in L-D area and sum of weight of each effectiveness parameter.
Detailed Description
The present invention will now be described in detail with reference to the drawings and specific embodiments, wherein the exemplary embodiments and descriptions are provided only for the purpose of illustrating the present invention and are not to be construed as limiting the present invention.
The quantitative evaluation method for the longitudinal oil-gas split ratio under the condition of the cap-breaking configuration in the specific embodiment takes an L-D area of an M basin as an example, a chalky formation is mainly developed in a research area and respectively comprises the following steps from bottom to top: a sand river group, a camp group, a marcfort storeroom group, a spring head group and the like. The oil and gas reservoir condition analysis result shows that two sets of regional mudstone cover layers are developed in the area D and are respectively positioned in the Ying three-section and the spring two-section, the main force cover layer in the area L is a Ying III sand group, and in order to fit a set of formula which is suitable for all areas, 31 measuring points are selected from all areas, and the method is used for carrying out fracture-cover configuration effectiveness evaluation on the measuring points.
(1) And determining a research area, selecting an evaluation layer position configured by breaking and covering, and selecting N measuring points.
(2) Microscopic angle evaluation: preferably selecting samples of each measuring point, testing the reservoir displacement pressure and the fault rock displacement pressure of each measuring point, and calculating the variable X according to the formula (3)1The calculation results are shown in table 1.
(3) And (3) macroscopic angle evaluation: calculating fault distance and cover layer thickness of each measuring point by using single well logging, layering and three-dimensional seismic data, and calculating variable X according to formula (4)2The calculation results are shown in table 1.
(4) And (3) evaluating a space angle: reading related data, calculating the SGR value of the fault rock of each measuring point according to a formula (9), and calculating the SGR by using a formula (10)llimCalculating the variable X according to equation (5)3The calculation results are shown in table 1.
(5) Evaluation of time angle: determining the oil and gas accumulation time T and the period according to experimental tests such as inclusion and the like; determining the time of flight T of a fault from seismic dataaAnd rest time Ts(ii) a According to the triaxial compression test, determining the brittleness-plasticity property of the cover layer in the geological historical period so as to determine the brittleness deformation time T of the cover layerbBrittle-plastic deformation time T of cap layerb-p. The variable X is calculated according to the equations (6), (7) and (8)4The specific parameters are shown in Table 2, and the calculation results are shown in Table 1.
(6) Acquiring a fault dip angle: and reading related data according to the three-dimensional seismic data, and determining the fault dip angle. The calculation results are shown in table 1.
(7) Calculating the longitudinal flow-dividing proportion of the oil gas on the target cover layer and the oil gas on the target cover layer of each well: logging, logging and using single well,The oil-gas enrichment degree R above the cover layer is calculated by using a formula (11) on the basis of determining the assignment, the corresponding thickness and the sandstone thickness of each oil-gas display grade of different data according to the oil-gas test dataa onAnd degree of oil and gas enrichment R under the cover layera is underAnd then, the formula (1) is used for respectively calculating the ratio of the oil gas accumulation effective values above and below the cover layer of the well where the measuring point is located, so as to obtain the dependent variable Y, the method is disclosed in the invention patent application with the patent number 201811108390.9, detailed description is not needed, and the calculation result is shown in table 1.
(8) Fitting formula: counting the migration coefficient and the storage coefficient of each parameter of the broken-cover configuration, and calculating to obtain the numerical value of each variable; according to four independent variables X1，X2，X3，X4Setting the assignment of each variable, wherein the angle evaluation variable of the microscopic displacement pressure is 0.4, the macroscopic angle evaluation variable is 0.2, the space effectiveness evaluation variable is 0.3, and the time effectiveness evaluation variable is 0.1; calculating and summing products of the numerical values of the respective variables and corresponding weights, and establishing a quantitative relation between the products and the longitudinal oil-gas flow splitting ratio and the fracture dip angle; through regression statistics of parameters, on the basis of weight assignment of each variable, a mathematical relation formula of independent variables and dependent variables is established by combining fault dip angles, as shown in a formula (11), and the mathematical relation formula is used for quantitative evaluation of oil-gas longitudinal flow splitting ratio under a cover-breaking configuration condition, as shown in a figure 2.
Y＝3.599cosθ(0.4X1+0.2X2+0.3X3+0.1X4)3.2706 (11)
TABLE 1L-D area disconnection-cover coupling control storage evaluation parameter statistical table
TABLE 2L-D area disconnection-cover coupling time validity parameter statistical table
According to the fitting result, the correlation of the established mathematical relational expression can reach 82.73%, the relative matching degree of the model is good, and the formula can be used for quantitatively judging the longitudinal oil-gas flow-dividing proportion under the cover-cover configuration.
The invention relates to a quantitative evaluation method of oil-gas longitudinal flow-dividing proportion under the condition of cut-cover configuration, which sets and evaluates each parameter of cut-cover (fault and cover layer) configuration relation from two angles of migration and storage respectively according to four aspects of macroscopicity, microcosmic, space and time, determines the mathematical relation of each parameter and the oil-gas longitudinal flow-dividing proportion on and under the cover layer on the basis of determining the oil-gas enrichment degree of different layers of wells, and further determines the control effect of cut-cover configuration on oil-gas longitudinal flow-dividing. The method is suitable for the research area of multilayer oil-gas-containing. Under the condition that reservoir formation factors such as oil gas filling conditions, reservoir conditions and the like are basically consistent in development, the longitudinal shunting effect of the cap-breaking configuration on oil gas is determined according to quantitative evaluation of the cap-breaking configuration relation, and the method has important significance on deployment of oil gas longitudinal exploration layer series.
The above description is only a preferred embodiment of the present invention, and all equivalent changes or modifications of the structure, characteristics and principles described in the present invention are included in the scope of the present invention.
Claims (3)
1. A quantitative evaluation method of oil-gas longitudinal flow-dividing proportion under a cover-breaking configuration condition is characterized by comprising the following steps:
step 1, determining a research area, selecting an evaluation horizon configured by a broken cover, and selecting N measuring points;
step 2, microscopic angle evaluation: testing the reservoir displacement pressure and the fault rock displacement pressure of each measuring point according to a formula
Calculating variable X1(ii) a Wherein, X1Is a microscopic evaluation variable; prThe pressure is discharged for the reservoir, unit MPa; pfFor the pressure, unit, of fault rockMPa；
Step 3, macroscopic angle evaluation: calculating fault distance and cover layer thickness of each measuring point by using single well logging, layering and three-dimensional seismic data according to a formula
Calculating variable X2(ii) a Wherein, X2Is a macroscopic evaluation variable; hfIs the fault distance in m; hcIs the cap layer thickness, in m;
step 4, evaluating a space angle: reading the relevant data according to the formula
Calculating SGR value of fault rock of each measuring point, and then utilizing formula
Computing SGRlimAccording to the formula
Calculating variable X3(ii) a Wherein, X3Is a space evaluation variable; SGRllimConfiguring an effective SGR lower limit for the cut-and-cover; SGR is the coating mud ratio of the fault mudstone; vsh storeThe content of reservoir mud is percentage; t isBreak-offThe unit Ma is the time for the fault rock to start diagenetic action; t isStore upThe unit Ma is the compaction diagenesis action time of the fault rock surrounding rock; rhorFor overburden density, units of g/cm3；ρwIs the density of the water of the stratum in g/cm3(ii) a Theta is the fracture dip angle in degrees;
step 5, time angle evaluation: determining the oil and gas accumulation time T and the period according to inclusion experiment tests; determining the time of flight T of a fault from seismic dataaAnd rest time Ts(ii) a According to the triaxial compression test, determining the brittle plasticity of the cover layer in the geological history period, thereby determining the brittle deformation time T of the cover layerbBrittle plastic deformation time T of cap layerb-p(ii) a According to the formula
Fm4＝0.9×Ta/T+0.1×Ts/T、Fp4＝0.3×Tb/T+0.7×Tb-p/T、
Calculating variable X4(ii) a Wherein, X4Is a time evaluation variable; t is the storage period time in Ma; t isaIs fault activity time, unit Ma; t issIs the fault rest time in unit Ma; t isbIs the brittle deformation time of the cap layer, in units of Ma; t isb-pIs the cap brittleness-plastic deformation time, unit Ma;
step 6, acquiring a fracture inclination angle: reading related data according to the three-dimensional seismic data, and determining a fracture dip angle;
step 7, calculating the longitudinal flow-dividing proportion of the upper oil gas and the lower oil gas of the target cover layer of each well: the formula R is used on the basis of determining the value assignment, the corresponding thickness and the sandstone thickness of each oil gas display level of different data by using the logging, logging and oil testing data of a single wella＝3.331P1-0.111P2-0.477P3+29.139, calculating the degree of hydrocarbon enrichment R above the cap layera onAnd degree of oil and gas enrichment R under the cover layera is underThen using the formula
Respectively calculating the ratio of the oil gas accumulation effective values above and below the cover layer of the well where the measuring point is located, namely the longitudinal flow-dividing ratio of oil gas, so as to obtain a dependent variable Y;
step 8, fitting a formula, establishing a mathematical relation formula of independent variables and dependent variables by combining fault dip angles on the basis of weight assignment of each variable, and quantitatively judging the longitudinal oil-gas flow-dividing proportion under the fault-cover configuration; the method comprises the following specific steps: counting the migration coefficient and the storage coefficient of each parameter of the broken-cover configuration, and calculating to obtain the numerical value of each variable; according to four independent variables X1、X2、X3、X4Setting the assignment of each variable, wherein the microscopic evaluation variable is 0.4, the macroscopic evaluation variable is 0.2,the spatial evaluation variable was 0.3 and the temporal evaluation variable was 0.1; calculating and summing products of the numerical values of the respective variables and corresponding weights, and establishing a quantitative relation between the products and the longitudinal oil-gas flow splitting ratio and the fracture dip angle; through regression statistics of parameters, on the basis of weight assignment of each variable, a mathematical relation between independent variables and dependent variables is established by combining fault dip angles: y3.599 cos θ (0.4X)1+0.2X2+0.3X3+0.1X4)3.2706The method is used for quantitative evaluation of the oil-gas longitudinal flow-dividing proportion under the condition of cover-breaking configuration.
2. The quantitative evaluation method of the oil-gas longitudinal flow-dividing proportion under the condition of the cover-breaking configuration according to claim 1, characterized in that in step 1, a research area is determined, an evaluation horizon for the cover-breaking configuration is selected, N measuring points are selected, and the cover-breaking configuration deposit control effect quantitative evaluation is performed on the measuring points.
3. The quantitative evaluation method of the longitudinal oil-gas flow splitting ratio under the condition of the cap-breaking configuration according to claim 1, wherein in step 6, relevant data are read according to three-dimensional seismic data to determine a fracture dip angle.
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