CN104239743A - Method and device for determining reservoir forming probability of lithologic oil-gas reservoirs - Google Patents
Method and device for determining reservoir forming probability of lithologic oil-gas reservoirs Download PDFInfo
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Abstract
The invention provides a method and device for determining the reservoir forming probability of lithologic oil-gas reservoirs. The method includes the steps that the phase index is calculated, the potential index is calculated, and the phase-potential coupling index is calculated according to the phase index and the potential index; the source control index is calculated; the phase-potential-source composite reservoir-controlling index is calculated through the phase index, the potential index and the source control index; the above steps are executed repeatedly, so that the phase-potential-source composite reservoir-controlling index of each lithologic oil-gas reservoir in the multiple lithologic oil-gas reservoirs to be analyzed is obtained through calculation; the quantitative relation between the phase-potential-source composite reservoir-controlling indexes and the reservoir forming probability is established, and the reservoir forming probability of the lithologic oil-gas reservoirs in a research area is analyzed according to the established quantitative relation. By the adoption of the method and device, the technical problems that reservoir forming probability forecasting of the lithologic oil-gas reservoirs in the prior art still stays in the semi-quantitative stage, and accurate quantitative research can not be achieved are solved, and therefore the quantitative research purpose of the reservoir forming probability of the lithologic oil-gas reservoirs is achieved.
Description
Technical field
The present invention relates to oil gas prospecting technique field, particularly a kind of method and apparatus determining lithologic reservoir forming probability.
Background technology
The trapped formation probability of lithologic deposit refers to the possibility size of oily in a certain trap, can become to hide for evaluating this trap, simultaneously Hydrocarbon Formation Reservoirs probability is also used for characterizing the size that the hydrocarbon resources such as petroleum gas can assemble the possibility of oil gas in certain area or exploration targets, Hydrocarbon Formation Reservoirs probability is larger, and the possibility that rich accumulation of oil and gas becomes to hide is higher.Study into Tibetan probability and effectively can determine exploration targets, efficiency evaluation can also be carried out to target simultaneously, in exploration process, target can be implemented to concrete wellblock by concrete evaluation result, thus exploration risk and prospecting prime cost can be reduced, improve drilling success, the increasing the storage for oil field provides clearer and more definite foundation and important guarantee.
Therefore, in oil exploration and exploitation, the Hydrocarbon Enrichment Regularity of study area lithologic deposit is the problem that people are concerned about with becoming to hide probability always, the analysis of lithologic reservoir forming Dominated Factors and quantitative examination thereof are directly connected to the success ratio of oil-gas exploration, but, due to the complicacy of geologic condition and the uncertainty of accumulating condition, the progress making into Tibetan probability is slow.
For the research of lithologic deposit Hydrocarbon Enrichment Regularity, particularly become to hide this problem of quantitative examination of probability for it, at present multiple method is proposed, such as: phased trapped formation probabilistic forecasting, gesture control trapped formation probabilistic forecasting, source control trapped formation probabilistic forecasting, but generally speaking, these methods are all based on monofactorial, hide probabilistic forecasting still rest on semidefinite quantization stage, also unrealized accurate quantitative examination to the one-tenth of lithologic deposit.
Summary of the invention
Embodiments provide a kind of method determining lithologic reservoir forming probability, realize hiding to the one-tenth of lithologic deposit the object that probability carries out quantitative examination to reach, the method comprises:
According to porosity data and the permeability data of the reservoir of lithologic deposit to be analyzed in study area, calculate phase index;
According to pore throat radius data and the interfacial tension data of described reservoir, calculate gesture index;
Gesture index according to described phase exponential sum, calculates the phase gesture index of coupling;
Utilize the Distance geometry oil gas that the hydrocarbon source rock in described study area arranges hydrocarbon intensity, oil gas is hidden within Pai Ting center to be hidden within the distance of arranging hydrocarbon border, calculate source control index;
Utilize control index in source described in described phase index, described gesture exponential sum, calculate the control of phase potential source compound and hide index;
Repeat above-mentioned steps, index is hidden in the phase potential source compound control calculating each lithologic deposit in multiple lithologic deposit to be analyzed;
The one-tenth Tibetan probability multiple phase potential source compound controls obtained being hidden to each lithologic deposit to be analyzed of exponential sum is added up, and sets up the control of phase potential source compound and hides index and the quantitative relationship becoming to hide between probability;
Hide index and the quantitative relationship becoming to hide between probability according to the phase potential source compound control of setting up, probability is hidden to the one-tenth of the lithologic deposit in described study area and analyzes.
In one embodiment, according to porosity data and the permeability data of the reservoir of lithologic deposit to be analyzed in study area, calculate phase index, comprising:
Obtain porosity data and the permeability data of described reservoir;
Calculate relative porosity according to the porosity data obtained, calculate relative permeability according to the permeability data obtained;
Phase index is calculated according to described relative porosity and relative permeability.
In one embodiment, according to following formulae discovery relative porosity:
Φ
i＝Φ/Φ
max
Wherein, Φ represents reservoir porosity, Φ
maxrepresent the maximum reservoir porosity under same depth conditions, Φ
irepresent relative porosity;
According to following formulae discovery relative permeability:
K
i＝lg(K)/lg(K
max)
Wherein, K represents reservoir permeability, and unit is 10
-3μm
2, K
maxrepresent the maximum reservoir permeability under same depth conditions, unit is 10
-3μm
2, K
irepresent relative permeability;
According to described relative porosity and relative permeability according to following formulae discovery phase index:
FI＝(Φ
i+K
i)/2
Wherein, FI represents phase index, and value is 0 ~ 1, Φ
irepresent relative porosity, K
irepresent relative permeability.
In one embodiment, by described pore throat radius data and interfacial tension data, calculate gesture index, comprising:
According to following formulae discovery interface-potential;
Wherein, P represents interface-potential, and σ represents interfacial tension, and θ represents heterogeneous fluid contact angle, and r represents pore throat radius;
According to following formulae discovery gesture index:
PI＝(P
s-P
min)/(P
max-P
min)
Wherein, PI represents gesture index, and value is 0 ~ 1, P
srepresent the interface-potential of reservoir self, P
minrepresent the interface-potential of the sandstone that pore throat radius under same Conditions of Buried Depth is maximum, P
maxrepresent the mud stone interface-potential under same Conditions of Buried Depth.
In one embodiment, according to described phase exponential sum gesture index according to the following formulae discovery phase gesture index of coupling;
Wherein, FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, FI represents phase index, and PI represents gesture index.
In one embodiment, according to following formulae discovery source control index:
Wherein, SI represents source control index, and value is 0 ~ 1, L
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to Pai Ting center, l
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to row hydrocarbon border, qe represents maximum row's hydrocarbon intensity of hydrocarbon source rock, and unit is 10
6t/km
2.
In one embodiment, the distance of standardized hydrocarbon-bearing pool to Pai Ting center is obtained according to following formulae discovery:
L
standardization=L/L
0
The distance of standardized hydrocarbon-bearing pool to row hydrocarbon border is obtained according to following formulae discovery:
L
standardization=l/L
0
Wherein, L represents the distance of hydrocarbon-bearing pool to Pai Ting center, and l represents the distance of hydrocarbon-bearing pool to row hydrocarbon border, L
0represent along L direction, Pai Ting center is to the distance on row hydrocarbon border.
In one embodiment, index is hidden according to following formulae discovery phase potential source compound control:
FPSI＝(FPI+SI)/2
Wherein, FPSI represents that index is hidden in the control of phase potential source compound, and FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, SI represents source control index, and value is 0 ~ 1.
In one embodiment, described lithologic deposit to be analyzed is the hydrocarbon-bearing pool and the trap that falls through that have found in study area.
The embodiment of the present invention additionally provides a kind of device determining lithologic reservoir forming probability, and realize hiding to the one-tenth of lithologic deposit the object that probability carries out quantitative examination to reach, this device comprises:
Phase exponent calculation unit, for porosity data and the permeability data of the reservoir according to lithologic deposit to be analyzed in study area, calculates phase index;
Gesture exponent calculation unit, for according to the pore throat radius data of described reservoir and interfacial tension data, calculates gesture index;
Phase gesture index of coupling computing unit, for gesture index according to described phase exponential sum, calculates the phase gesture index of coupling;
Source control exponent calculation unit, for utilizing the Distance geometry oil gas that the hydrocarbon source rock in described study area arranges hydrocarbon intensity, oil gas is hidden within Pai Ting center to be hidden within the distance of arranging hydrocarbon border, calculates source control index;
Exponent calculation unit is hidden in the control of phase potential source compound, for utilizing control index in source described in described phase index, described gesture exponential sum, calculating the control of phase potential source compound and hiding index;
Repeat unit, for repeating above-mentioned steps, index is hidden in the phase potential source compound control calculating each lithologic deposit in multiple lithologic deposit to be analyzed;
Quantitative relationship determining unit, the one-tenth for hiding each lithologic deposit to be analyzed of exponential sum to the multiple phase potential source compound controls obtained is hidden probability and is added up, and sets up the control of phase potential source compound and hides index and the quantitative relationship becoming to hide between probability;
Analytic unit, for hiding index and the quantitative relationship becoming to hide between probability according to the phase potential source compound control of setting up, hiding probability to the one-tenth of the lithologic deposit in described study area and analyzing.
In embodiments of the present invention, first calculate phase index, gesture exponential sum source control index, then the phase gesture index of coupling is calculated according to phase exponential sum gesture index, calculate the control of phase potential source compound according to the phase gesture index of coupling and source control index and hide index, the last phase potential source compound control analyzing the lithologic deposit in multiple region to be analyzed is again hidden exponential sum and is become to hide probability, thus realize the analysis of hiding probability based on the one-tenth of the comprehensive lithologic deposit of phase potential source, thus solve and in prior art, probabilistic forecasting is hidden to the one-tenth of lithologic deposit and still rest on semidefinite quantization stage, the also technical matters of unrealized accurate quantitative examination, reach and the object that probability carries out quantitative examination is hidden to the one-tenth of lithologic deposit.
Accompanying drawing explanation
Accompanying drawing described herein is used to provide a further understanding of the present invention, forms a application's part, does not form limitation of the invention.In the accompanying drawings:
Fig. 1 is the method flow diagram of the determination lithologic reservoir forming probability of the embodiment of the present invention;
Fig. 2 is the hydrocarbon-bearing pool of the embodiment of the present invention and the phase exponential sum gesture exponential distribution schematic diagram of the trap that falls through;
Fig. 3 is the distribution schematic diagram of the phase gesture coupling control Zang Zhishuoheyuan control index of the embodiment of the present invention;
Fig. 4 is the distribution schematic diagram of the phase potential source compound control Tibetan index of the embodiment of the present invention;
Fig. 5 is the phase potential source compound control Tibetan index of the embodiment of the present invention and the relation schematic diagram of Hydrocarbon Formation Reservoirs probability;
Fig. 6 is the apparatus structure block diagram of the determination lithologic reservoir forming probability of the embodiment of the present invention.
Embodiment
For making the object, technical solutions and advantages of the present invention clearly understand, below in conjunction with embodiment and accompanying drawing, the present invention is described in further details.At this, exemplary embodiment of the present invention and illustrating for explaining the present invention, but not as a limitation of the invention.
Inventor considers, the one-tenth affecting lithologic deposit hides the factor of probability a lot, such as, and hydrocarbon source stove, geology phase and fluid potential.Simultaneously the jointly controlling of these factors such as hydrocarbon source stove, phase and fluid potential, macroscopically control the spatial and temporal distributions of hydrocarbon-bearing pool, the oil-gas possibility that microcosmic controls hydrocarbon-bearing pool changes, and can hide referred to as the control of phase potential source compound.But current most research is all based on monofactorial research, also lack the quantitative examination to phase, gesture, source compound hydrocarbon control action, that is, also do not set up the quantitative examination pattern based on phase, gesture, source three's compound, thus the quantitative examination of Hydrocarbon Formation Reservoirs probability is never effectively developed.
In order to clearly illustrate the embodiment of the present invention, first phase, gesture, source three are simply described below:
1) phase, this concept is the earliest by Denmark sand smeller Si Dannuo (N.Steno, 1669) first Geologic Documents is introduced, Switzerland sand smeller lattice Leslie (A.Gressly in 1838,1838) start the concept of phase to be used for sedimentogeneous rock, he thinks it is the summation of sediment change mutually, it show as this or that lithology, geology or the difference of extinct plants and animal.Teichert (1958) and Krumbein and Sloss (1963) have done good summary to this, be a kind of lithosome with special characteristic mutually.
Earlier 1900s so far, the concept of phase is widely popular along with the development of sedimentology, palaeogeography, many scholars have carried out detailed discussion to it, comprehensive, be exactly the material exhibits of that formed under certain condition, that specific environment or process can be reflected sediment (rock) mutually.
When being applied to rich accumulation of oil and gas Cheng Zangzhong, the concept of phase is construed as the performance of the dielectric attribute of oil-gas migration and accumulation, the content of forgiving according to phase and controlling factor, four different research level can be divided into from macroscopic view to microscopic sdIBM-2+2q.p.approach: structure phase, sedimentary facies, rock phase and high water cut, different levels in oil-gas exploration, have different implications to the control action of rich accumulation of oil and gas.
For the study area that exploration and development data is more complete, high water cut is one of lithologic reservoir forming Dominated Factors, the physics of rock refers to the reservoir genesis unit with certain rock physical property mutually, it is the comprehensive effect of deposition, Diagn and later structural effect, it finally shows as reservoir pore space network characterization now, and the final sign of high water cut is the high level overview model of fluid neuron network pore network dielectric attribute.When practical application, the general parameter such as factor of porosity, permeability, median size that can characterize reservoir rock physical features of selecting carrys out quantitative evaluation reservoir rock physics phase.Wherein, the physical property characteristic of factor of porosity, permeability reflection reservoir is direct, the most quantitative characterization parameter of high water cut, and factor of porosity is the parameter weighing rock Reservoir Fluid ability, and permeability weighs the parameter that rock transmits fluid capacity.Therefore, rock porosity, permeability the most directly weigh and affect two physical parameters of fluid in rock (comprising oil gas), and the size of these two parameters and homogenieity control the freight index future of oil gas in blowhole.
2) along with the development of Quantitative research method, fluid potential is made to become possibility for the computer simulation of oil-gas migration, gathering, current fluid potential plays a part more and more important in oil-gas migration, gathering, and current three-dimensional gesture is extremely oil geology worker attention.
Under the geologic condition of reality, according to the difference controlling the controlled factor of oil gas, fluid potential can be divided into following four kinds: the potential energy that buoyancy produces, the pressure energy that Overpressure produces, the kinetic energy etc. of the inertia generation of the interfacial energy that capillary pressure function produces and water flow, wherein, different potential energy controls the forming and distribution of dissimilar hydrocarbon-bearing pool, for lithologic deposit, under the effect of capillary force, migrate in the sandstone of the low interfacial energy that oil gas is always larger to pore throat radius in the mud stone of high interfacial energy or the little sandstone of pore throat radius, final enrichment becomes various typical lithologic deposit.
3) in the process of petroleum prospecting, also have a kind of research theoretical, opinion is controlled in source of crying, along with going deep into source control opinion research, it is found that Bohai gulf basin hydrocarbon occurrence also controls by source sag, each source sag has respective oil and gas geochemistry feature, differs greatly between them, main relevant with maturity with each depression oil source rock Organic matter type.Source control opinion emphasizes that oil gas field distributes around oil-generating center, and be subject to the strict control in oil generation district, also someone thinks that oil gas field all has independently sedimentation unit and an oil-generating center of one's own around source sag, an oil-generating center is exactly a rich accumulation of oil and gas center, namely oil-gas generation, migration, gathering control by oil-gas generation center completely, and oil-gas pool distribution is ring-band shape distribution around oil-generating center.In addition, by showing the statistics of Continental Petroliferous Basins, there are two measurement indexs in the raw hydrocarbon intensity that can form commercial hydrocarbon flow: one is that maximum raw hydrocarbon intensity is greater than 1 × 106t/km
2, another on average gives birth to hydrocarbon intensity to be greater than 0.5 × 106t/km
2, the angry intensity of source rock forming super-huge natural gas pool need more than 50 × 108m3/km
2, the angry intensity forming medium gas fields need more than 20 × 108m
3/ km
2if the angry intensity of study area source rock is lower than 10 × 108m
3/ km
2, then find the possibility in gas field less.From above-mentioned discussion, the control action of hydrocarbon source rock to oil gas is not only the regularity of distribution controlling oil gas, but also controls Hydrocarbon Formation Reservoirs probability and become Tibetan scale.
In this example, just based on above-mentioned phase, gesture, three kinds, source geologic agent, propose and a kind ofly combine the method determining lithologic reservoir forming probability, as shown in Figure 1, comprise the following steps:
Step 101: according to porosity data and the permeability data of the reservoir of lithologic deposit to be analyzed in study area, calculates phase index;
Step 102: according to pore throat radius data and the interfacial tension data of described reservoir, calculates gesture index;
Step 103: gesture index according to described phase exponential sum, calculates the phase gesture index of coupling;
Step 104: utilize the Distance geometry oil gas that the hydrocarbon source rock in described study area arranges hydrocarbon intensity, oil gas is hidden within Pai Ting center to be hidden within the distance of arranging hydrocarbon border, calculates source control index;
Step 105: utilize control index in source described in described phase index, described gesture exponential sum, calculates the control of phase potential source compound and hides index;
Step 106: repeat above-mentioned steps, index is hidden in the phase potential source compound control calculating each lithologic deposit in multiple lithologic deposit to be analyzed;
Step 107: the one-tenth Tibetan probability multiple phase potential source compound controls obtained being hidden to each lithologic deposit to be analyzed of exponential sum is added up, and sets up the control of phase potential source compound and hides index and the quantitative relationship becoming to hide between probability;
Step 108: hide index and the quantitative relationship becoming to hide between probability according to the phase potential source compound control of setting up, hides probability to the one-tenth of the lithologic deposit in described study area and analyzes.
In the above-described embodiments, first calculate phase index, gesture exponential sum source control index, then the phase gesture index of coupling is calculated according to phase exponential sum gesture index, calculate the control of phase potential source compound according to the phase gesture index of coupling and source control index and hide index, the last phase potential source compound control analyzing the lithologic deposit in multiple region to be analyzed is again hidden exponential sum and is become to hide probability, thus realize the analysis of hiding probability based on the one-tenth of the comprehensive lithologic deposit of phase potential source, thus solve and in prior art, probabilistic forecasting is hidden to the one-tenth of lithologic deposit and still rest on semidefinite quantization stage, the also technical matters of unrealized accurate quantitative examination, reach and the object that probability carries out quantitative examination is hidden to the one-tenth of lithologic deposit.
Can be known by the above-mentioned analysis to phase, the factor affecting phase mainly contains porosity and permeability, therefore can calculate phase index by permeability and factor of porosity, and concrete, above-mentioned steps 101 can comprise:
Step 1: the porosity data and the permeability data that obtain reservoir; ;
Step 2: calculate relative porosity according to the porosity data obtained, calculates relative permeability according to the permeability data obtained, concrete:
Can according to following formulae discovery relative porosity:
Φ
i＝Φ/Φ
max
Wherein, Φ represents reservoir porosity, Φ
maxrepresent the maximum reservoir porosity under same depth conditions, Φ
irepresent relative porosity;
Can according to following formulae discovery relative permeability:
K
i＝lg(K)/lg(K
max)
Wherein, K represents reservoir permeability, and unit is 10
-3μm
2, K
maxrepresent the maximum reservoir permeability under same depth conditions, unit is 10
-3μm
2, K
irepresent relative permeability;
Step 3: calculate phase index according to described relative porosity and relative permeability;
Concrete, can according to following formulae discovery phase index:
FI＝(Φ
i+K
i)/2
Wherein, FI represents phase index, and value is 0 ~ 1, Φ
irepresent relative porosity, K
irepresent relative permeability.
Migrate in sandstone in view of always larger to pore throat radius in the mud stone of high interfacial energy or the little sandstone of the pore throat radius low interfacial energy of oil gas, final enrichment becomes various typical lithologic deposit, therefore, can by described pore throat radius data and interfacial tension data, calculate gesture index, during concrete enforcement, above-mentioned steps 102 calculates gesture index and can comprise:
Step 1: according to following formulae discovery interface-potential;
Wherein, P represents interface-potential, and σ represents interfacial tension, and θ represents heterogeneous fluid contact angle, and r represents pore throat radius;
Step 2: according to following formulae discovery gesture index:
PI＝(P
s-P
min)/(P
max-P
min)
Wherein, PI represents gesture index, and value is 0 ~ 1, P
srepresent the interface-potential of reservoir self, P
minrepresent the interface-potential of the sandstone that pore throat radius under same Conditions of Buried Depth is maximum, P
maxrepresent the mud stone interface-potential under same Conditions of Buried Depth.
During concrete enforcement, according to following formula, the phase gesture index of coupling can be calculated by phase exponential sum gesture index;
Wherein, FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, FI represents phase index, and PI represents gesture index.
Index can be controlled according to following formulae discovery source:
Wherein, SI represents source control index, and value is 0 ~ 1, L
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to Pai Ting center, l
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to row hydrocarbon border, qe represents maximum row's hydrocarbon intensity of hydrocarbon source rock, and unit is 10
6t/km
2.
Above-mentioned employing standardization processes data, and mainly in order to weaken the impact of geologic condition on parameter, concrete, standardization formula is as follows:
L
standardization=L/L
0
L
standardization=l/L
0
Wherein, L represents the distance of hydrocarbon-bearing pool to Pai Ting center, and l represents the distance of hydrocarbon-bearing pool to row hydrocarbon border, L
0represent along L direction, Pai Ting center is to the distance on row hydrocarbon border.
After determining the phase gesture index of coupling and source control index, index can be hidden according to following formulae discovery phase potential source compound control:
FPSI＝(FPI+SI)/2
Wherein, FPSI represents that index is hidden in the control of phase potential source compound, and FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, SI represents source control index, and value is 0 ~ 1.
In each embodiment above-mentioned, lithologic deposit to be analyzed is the hydrocarbon-bearing pool and the trap that falls through that have found in study area, and so just accurately can know that the one-tenth in analyzed region hides probability, thus determine that index and the relation becoming to hide between probability are hidden in the control of phase potential source compound.
In order to further illustrate the present invention, determine that the method for the one-tenth Tibetan probability of lithologic deposit is specifically described below in conjunction with a specific embodiment to of the present invention, but it should be noted that, this specific embodiment is only to better the present invention is described, does not form inappropriate limitation of the present invention.
In this example, propose a kind of method of quantitative forecast lithologic reservoir forming probability, utilize the data such as the high water cut of lithologic deposit, interface-potential and hydrocarbon source stove, based on the actual geologic condition in study area, objective, to dope study area lithologic deposit exactly one-tenth hides probability, specifically comprises the following steps:.
Step 1: calculate phase index FI, comprising:
1) reservoir porosity is obtained by the method such as logging trace Interpretation On The Results or core physical property analysis, or can the factor of porosity of prediction rock and maximum porosity by the granule size of rock, sorting and matrix content etc., concrete predictor formula is:
Φ=f (D, N, S...) (formula 1)
Φ
max=f (D, N, S...) (formula 2)
Wherein, Φ represents reservoir porosity, and unit is that %, D represent particle diameter, and unit is μm, and N represents matrix content, and unit is that %, S represent sorting coefficient, dimensionless, Φ
maxrepresent the maximum reservoir porosity under same depth conditions, unit is %;
2) relative porosity of reservoir rock is asked for by the ratio of rock porosity and maximum porosity:
Φ
i=Φ/Φ
max(formula 3)
Wherein, Φ
irepresent relative porosity.
3) by the permeability of the parameter prediction rock such as granule size, shale index, sorting coefficient of rock:
K=f (D, N, S...) (formula 4)
Reservoir principal permeability can be asked for by the funtcional relationship of known reservoir principal permeability value and the degree of depth:
K
max=f (D, N, S...) (formula 5)
4) relative permeability of reservoir rock is gone out according to following formulae discovery, namely rock particles permeability and the ratio with principal permeability under depth conditions is calculated, in actual applications, because the numerical value difference of permeability is comparatively large, ratio of therefore taking the logarithm more can embody the effect of permeability in the quantitative calculating of excellent phase:
K
i=lg (K)/lg (K
max) (formula 6)
Wherein, K represents reservoir permeability, and unit is 10
-3μm
2, K
maxrepresent the maximum reservoir permeability under same depth conditions, unit is 10
-3μm
2, K
irepresent relative permeability.
5) according to following formulae discovery phase index FI:
FI=(Φ
i+ K
i)/2 (formula 7)
Wherein, Φ
irepresent relative porosity, dimensionless, K
irepresent relative permeability, dimensionless, FI represents relatively excellent phase index, dimensionless.
Step 2: calculate gesture index:
The potential that interface-potential refers to heterogeneous fluid existence in subsurface rock and has, main relevant with the factor such as pore throat radius (r), fluid interface tension force (σ) of heterogeneous fluid contact angle (θ) size, rock medium, expression formula is:
Wherein, Φ
rrepresent interface-potential, θ represents heterogeneous fluid contact angle, and r represents the pore throat radius of rock medium, and σ represents fluid interface tension force;
The data needed for above-mentioned calculating interface-potential can be obtained in such a way:
1) by scanning electron microscope petroclastic rock observed and measure, analyzing form and the pore throat radius in the hole in mud stone, the pore throat radius of matching mud stone and depth relationship.
2) according to capillary pressure curve test, the average pore throat radius value of the different depth point trap sandstone of different well location, porosity value and permeability value is surveyed out, according to the relation of the pore throat radius of measured data matching trap sandstone and factor of porosity, permeability.
3) according to sandstone and factor of porosity, permeability relation fitting formula, ask for pore throat radius value, by corresponding with the degree of depth for the pore throat radius value asked for, draw the variation relation of the maximum pore throat radius of sandstone and the degree of depth.
4) based on the difference of interfacial tension σ with the degree of depth, by temperature, pressure change and the principle changed, the relation between matching σ and the degree of depth.
5) pore throat radius is calculated according to the size of physical properties of rock, combine the pore throat radius size of actual test again, calculate the size of relative potential energy, namely the pore throat radius size corresponding to the possible maximum interfacial energy of object series of strata reservoir is calculated by statistical value, and calculate maximum pore throat radius corresponding to the minimum interfacial energy of object series of strata, be normalized according to following formula and calculate relative interface potential energy index:
PSI=(P-P
min)/(P
max-P
min) (formula 9)
Wherein, PSI represents relative interface potential energy, and P represents the interface-potential of reservoir self, and unit is J, P
maxrepresent the interface-potential of the mud stone under same Conditions of Buried Depth, unit is J, P
minrepresent the interface-potential of the sandstone that pore throat radius under same Conditions of Buried Depth is maximum, unit is J.
Step 3: according to the following formulae discovery phase gesture index of coupling:
Wherein, FPI represents the phase gesture index of coupling, and value is 0 ~ 1, dimensionless, and FI represents excellent phase index, and value is 0 ~ 1, dimensionless, and PI represents low gesture index, and value is 0 ~ 1, dimensionless.
Step 4: calculate source control index, comprising:
1) according to study area actual hydrocarbon source rock data determination hydrocarbon source rock row hydrocarbon intensity qe, what hydrocarbon source rock row hydrocarbon intensity qe reflected is the distribution relation that hydrocarbon source rock arranges between hydrocarbon feature and hydrocarbon-bearing pool.
2) quantitatively characterizing oil gas is hidden within the distance (l) that the distance (L) at Pai Ting center and oil gas are hidden within row hydrocarbon border, wherein, the distance (L) that oil gas is hidden within Pai Ting center with Pai Ting center for initial point, represent the distance at hydrocarbon-bearing pool distance Pai Ting center, it is initial point that the distance (l) on row hydrocarbon border chooses row hydrocarbon border, get negative value within the scope of row's hydrocarbon, get outside row's hydrocarbon scope on the occasion of.
In order to weaken the impact of geologic condition on parameter, according to following formula, standardization is carried out to data:
L
standardization=L/L
0(formula 11)
L
standardization=l/L
0(formula 12)
Wherein, L
standardizationl value after expression standardization, dimensionless, l
standardizationl value after expression standardization, dimensionless, L represents that oil gas is hidden within the actual range at Pai Ting center, and unit is that km, l represent that oil gas is hidden within the actual range on row hydrocarbon border, and unit is km, L
0represent along L direction, Pai Ting center is to the distance on row hydrocarbon border, and unit is km.
3) single-factor regressioning analysis is carried out to each hydrocarbon-bearing pool Dominated Factors, hydrocarbon-bearing pool number generally reduces with the increase of row's hydrocarbon centre distance, and arranging hydrocarbon-bearing pool integrated distribution near hydrocarbon border, increase hydrocarbon-bearing pool quantity with row's hydrocarbon intensity exponentially increases, adopt the recurrence of nonlinear multivariable, set up source control formula of index:
Wherein, SI represents source control index, dimensionless.
Step 5: hide index according to following formulae discovery phase-gesture-source compound control:
FPSI=(FPI+SI)/2 (formula 14)
Wherein, FPSI represents that index is hidden in phase-gesture-source compound control, and value is 0 ~ 1, dimensionless.
Step 6: the phase-gesture-source compound control of the hydrocarbon-bearing pool found according to study area and the trap that falls through is hidden index FPSI and added up, set up phase-gesture-source compound control to hide and predict into Tibetan probability plate, set up FPSI and become the quantitative relation formula of Tibetan probability (RFPSI).
Be described for an application example district Jiyang Depression, The Bohaiwan Basin below, Jiyang depression is positioned at In The Northern Shandong Province, the adjacent Bohai Sea, east, to the Jinpu Railway, substantially be positioned at east longitude 116 ° 40 ~ 119 °, between north latitude 37 ° ~ 39 °, the textural southeast being in Bohai Sea Gulf rift basin, area 29000km2.Jiyang Depression resource through the exploration in more than 40 years, finishing drilling prospect pit 5870 mouthfuls, prospect pit density has reached 0.23 mouthful/km2, and by the end of the year 2005, accumulation verified oil geologic reserve will be 46.33 × 108t, and petroleum resources discovery degree reaches 57.20%; This district exploration time is long, data is more complete, numerous petroleum geologist carries out excessive quantity research for many years simultaneously, have accumulated plentiful and substantial achievement in research, be convenient to the research carrying out phase potential source compound control oil-gas reactivation determination lithologic reservoir forming probability, its result to the Exploration Domain in forecasting research district, indicate favo(u)rable target and be of great importance.
Reservoir rock relative porosity or relative permeability is calculated by above-mentioned formula 1 to 6, or, obtained physical property characteristic parameter factor of porosity Φ, the permeability K of part reservoir in study area by logging trace Interpretation On The Results, core physical property analysis or the experiment of rock pressure mercury, and calculate relative porosity or relative permeability.
According to relative porosity or relative permeability data, calculate phase index by above-mentioned formula 7.
Utilize scanning electron microscope to observe lower than being that 2700 holes of mud stone in 300m ~ 4000m depth range are wide to Jiyang depression the 3rd under 10000 times and measuring, analyze the form and the pore throat radius data that draw Jiyang depression mud stone mesopore.And utilize these data to carry out matching according to the pore throat radius of following formula 15 pairs of Jiyang depression mud stone and depth relationship:
R=6259.1H
-1.6542, R=0.949 (formula 15)
Wherein, r represents the pore throat radius of mud stone, and unit is μm, and H represents the degree of depth, and unit is that m, R represent degree of fitting.
Test according to capillary pressure curve, survey out the average pore throat radius value of Jiyang depression 58 mouthfuls of wells 219 different depth point trap sandstone, porosity value and permeability value, obtain the relation of the pore throat radius of trap sandstone and factor of porosity, permeability according to measured data matching:
Wherein, r represents the average pore throat radius of trap sandstone, and unit is μm,
represent factor of porosity, unit is that %, k represent permeability, and unit is 10
-3μm
2, R represents degree of fitting.
According to sandstone and factor of porosity, permeability relation fitting formula, obtain 24848 pore throat radius values, by corresponding with the degree of depth for the pore throat radius value asked for, draw the variation relation of the maximum pore throat radius of sandstone and the degree of depth in Dongying Depression trap:
R
max=-6 × 10
-6× H
2+ 0.02233 × H-2.1094 (H<3900m), R=0.849 (formula 17)
Wherein, r
maxrepresent maximum reservoir pore throat radius in region, unit is μm, and H represents depth of reservoirs, and unit is that m, R represent degree of fitting.
Interfacial tension σ is different with the degree of depth, and change by temperature, pressure change, the relational expression of matching σ and the degree of depth is:
σ=-5 × 10-6 × H+0.0249, R=0.9992 (formula 18)
Wherein, σ represents interfacial tension, and unit is that N/m, H represent depth of burial, and unit is that m, R represent degree of fitting.
According to above-mentioned formula 8, in conjunction with formula 15 to 18, calculate the interface-potential of different depth of burial.
546 hydrocarbon-bearing pools of statistical computation Jiyang depression statistics and the phase exponential sum gesture index of the trap that falls through, draw out the distribution schematic diagram of phase exponential sum gesture index as shown in Figure 2.
All FI>0.5 is positioned at as can be seen from the hydrocarbon-bearing pool of above-mentioned more than Fig. 2: 85%, in the scope of PI<0.6, most hydrocarbon-bearing pool all near from FI be 1 and PI be in the interval of 0, the closer to the upper right side of figure, the hydrocarbon-bearing pool of distribution is more, become to hide probability larger, the distributed area of the trap that falls through is in the lower left corner of figure.Therefore, this figure reflects the growth and decline relation of FI and PI of hydrocarbon-bearing pool in a certain sense, the position that phase index is low, and need the gesture index of hydrocarbon-bearing pool high, the position that gesture index is high, the number of phases of needs is low.Therefore, this figure also tentatively reflects that the relation between phase-gesture index of coupling with phase exponential sum gesture index is more complicated, by hypotenuse and the relation of two right-angle sides, the quantitative relationship between the phase gesture index of coupling and phase exponential sum gesture index can be described.
By the phase exponential sum gesture index determined, above-mentioned formula 10 is utilized to calculate phase gesture index of coupling FPI.
Above-mentioned formula 13 is utilized to calculate the source control index of each hydrocarbon-bearing pool and the trap that falls through, and the distribution relation figure of the phase gesture index of coupling of making as shown in Figure 3 and source control index.
As can be seen from above-mentioned Fig. 3: hydrocarbon-bearing pool more than 85% is all positioned at FPI>0.5, in the scope of SI>0.35, the closer to the upper right side of figure, the hydrocarbon-bearing pool of distribution is more, fall through the distributed area of trap in the lower left corner of figure, from figure, also can find out that phase gesture index of coupling FPI is proportionate with the probability that becomes to hide of hydrocarbon-bearing pool with nearly source index SI.
For husky three Central Asia sections of Dongying Depression, row's hydrocarbon intensity qe at the husky three Duan Paiting centers, the Central Asia of Dongying Depression can reach 17 × 10
6t/km
2, utilizes formula 14 to hide index FPSI to the phase potential source compound control of this interval and calculate, and exponential distribution schematic diagram is hidden in the phase potential source compound control that the region choosing FPSI>0.3 is drawn as shown in Figure 4.
As seen from Figure 4: Central anticlinal belt has large-scale Spring layer to distribute, northern steep slope zone and southern gentle slope belt also have a small amount of high Distribution value, reach as high as 0.7, also there is high Distribution value at Boxing Basin place, Spring layer history 119 wellblock of Central anticlinal belt, stick together 144 wellblocks, the phase potential source compound control Tibetan index seeking 691 wellblocks is respectively 0.795, 0.745, 0.65, the exploration targets that 3 of husky three Central Asia sections predictions of Dongying Depression are potential, be respectively ox 3-logical 4 pieces of lithologic deposits in bovine adipocyte south, Fan 124 lithologic deposit of Boxing Basin, profit 22-profit 982-sharp 90 lithologic deposits that Lijin is hollow, its phase potential source compound control is hidden index and is respectively 0.40, 0.53 and 0.68.
Hide index FPSI according to the phase potential source compound control of the hydrocarbon-bearing pool found a large amount of in Jiyang depression and the trap that falls through to add up, what establish FPSI as shown in Figure 5 and become to hide between probability RFPSI is quantitative, and quantitative relation formula formula 19:
RFPSI=1.1033 × FPSI-0.083, R
2=0.971 (formula 19)
As shown in table 1 is the trap 15 in Jiyang depression not being participated in into Tibetan probability statistics, applies the one-tenth Tibetan probabilistic forecasting formula obtained and carries out calculating obtained result.
Table 1
| Sequence number | Block | Depression title | Buried depth (m) | Layer position | FI | PI | FPI | SI | FPSI | Become to hide probability (%) |
| 1 | Large 19 pieces | Che Zhen | 2000 | Es2 | 0.69 | 0.29 | 0.70 | 0.73 | 0.51 | 0.79 |
| 2 | Large 52 pieces | Che Zhen | 3390 | Es2 | 0.69 | 0.20 | 0.75 | 0.79 | 0.59 | 0.87 |
| 3 | Single 10-73 wellblock | Dongying | 1165 | Es1 | 0.80 | 0.26 | 0.77 | 0.89 | 0.68 | 0.97 |
| 4 | Fan 26 | Dongying | 3065 | Es3 | 0.59 | 0.42 | 0.58 | 0.76 | 0.45 | 0.71 |
| 5 | Rich 11 | Dongying | 3170 | Es3 | 0.87 | 0.22 | 0.82 | 0.60 | 0.50 | 0.77 |
| 6 | Profit 2 pieces of the north | Dongying | 1995 | Es2 | 0.63 | 0.07 | 0.79 | 0.88 | 0.69 | 0.99 |
| 7 | Beam 35 nosing structure | Dongying | 3070 | Es3 | 0.59 | 0.05 | 0.79 | 0.68 | 0.54 | 0.81 |
| 8 | Ox 24-C | Dongying | 3057.5 | Es3 | 0.64 | 0.36 | 0.64 | 0.71 | 0.45 | 0.72 |
| 9 | History dark 100 | Dongying | 3280 | Es3 | 0.76 | 0.28 | 0.74 | 0.58 | 0.43 | 0.69 |
| 10 | King 57-A | Dongying | 3004 | Es3 | 0.49 | 0.61 | 0.44 | 0.62 | 0.27 | 0.52 |
| 11 | Face oblique 111 pieces | Huimin | 3690 | Es3 | 0.71 | 0.29 | 0.71 | 0.58 | 0.41 | 0.67 |
| 12 | Business 106 | Huimin | 1300 | Ng | 0.66 | 0.14 | 0.77 | 0.65 | 0.50 | 0.77 |
| 13 | Business 5-11 block | Huimin | 1900 | Es3 | 0.79 | 0.16 | 0.81 | 0.59 | 0.48 | 0.75 |
| 14 | A on Zheng 408-S3 | Dongying | 1340 | Es3 | 0.64 | 0.12 | 0.77 | 0.48 | 0.37 | 0.63 |
| 15 | Zheng 37 pieces | Dongying | 1280 | Es1 | 0.42 | 0.63 | 0.40 | 0.45 | 0.18 | 0.42 |
In the above-described embodiments, provide a kind of method based on phase potential source compound control oil-gas reactivation determination lithologic reservoir forming probability, mainly comprise: obtain reservoir porosity and permeability data in study area, calculate relative porosity and relative permeability; According to relative porosity and relative permeability, calculate phase index FI; Obtain reservoir rock pore throat radius and interfacial tension data, calculate interface-potential, i.e. gesture indices P I; Phase gesture index of coupling FPI is calculated by phase index FI and gesture indices P I; Utilize the Distance geometry oil gas that hydrocarbon source rock arranges hydrocarbon intensity, oil gas is hidden within Pai Ting center to be hidden within the distance of arranging hydrocarbon border, calculate source control index SI; Utilize phase index FI, gesture indices P I and source control index SI, calculate the control of phase potential source compound and hide index FPSI; Index FPSI is hidden in the phase potential source compound control of hydrocarbon-bearing pool in statistical research district, sets up FPSI and the quantitative relation formula becoming to hide probability.In this example, quantitatively calculate phase, gesture, source is to the control action of oil gas, by it with phase index, gesture exponential sum source control index characterizes, adopt source control index and the phase gesture index of coupling simultaneously, the control rich accumulation of oil and gas effect of index FPSI quantitatively characterizing is hidden with the control of phase potential source compound, establish the control of phase potential source compound and hide index FPSI and the relational expression and the relation schematic diagram that become to hide probability, this method solve a difficult problem for Jiyang Depression, The Bohaiwan Basin lithologic reservoir forming probability quantitative forecast, a kind of feasible technical method is provided for this area predicts Exploration Domain and indicates favo(u)rable target, reduce the risk of oil-gas exploration, specify the exploration trend of oil gas, there is applicability widely.
Based on same inventive concept, additionally provide a kind of device determining lithologic reservoir forming probability in the embodiment of the present invention, as described in the following examples.Similar to determining the method for lithologic reservoir forming probability owing to determining the principle that the device of lithologic reservoir forming probability is dealt with problems, therefore determine that the enforcement of the device of lithologic reservoir forming probability see the enforcement of method determining lithologic reservoir forming probability, can repeat part and repeat no more.Following used, term " unit " or " module " can realize the software of predetermined function and/or the combination of hardware.Although the device described by following examples preferably realizes with software, hardware, or the realization of the combination of software and hardware also may and conceived.Fig. 6 is a kind of structured flowchart of the device of the determination lithologic reservoir forming probability of the embodiment of the present invention, as shown in Figure 6, comprise: phase exponent calculation unit 601, gesture exponent calculation unit 602, phase gesture index of coupling computing unit 603, source control exponent calculation unit 604, the control of phase potential source compound are hidden exponent calculation unit 605, repeated unit 606, quantitative relationship determining unit 607 and analytic unit 608, are described below to this structure.
Phase exponent calculation unit 601, for porosity data and the permeability data of the reservoir according to lithologic deposit to be analyzed in study area, calculates phase index;
Gesture exponent calculation unit 602, for according to the pore throat radius data of described reservoir and interfacial tension data, calculates gesture index;
Phase gesture index of coupling computing unit 603, for gesture index according to described phase exponential sum, calculates the phase gesture index of coupling;
Source control exponent calculation unit 604, for utilizing the Distance geometry oil gas that the hydrocarbon source rock in described study area arranges hydrocarbon intensity, oil gas is hidden within Pai Ting center to be hidden within the distance of arranging hydrocarbon border, calculates source control index;
Exponent calculation unit 605 is hidden in the control of phase potential source compound, for utilizing control index in source described in described phase index, described gesture exponential sum, calculating the control of phase potential source compound and hiding index;
Repeat unit 606, for repeating above-mentioned steps, index is hidden in the phase potential source compound control calculating each lithologic deposit in multiple lithologic deposit to be analyzed;
Quantitative relationship determining unit 607, the one-tenth for hiding each lithologic deposit to be analyzed of exponential sum to the multiple phase potential source compound controls obtained is hidden probability and is added up, and sets up the control of phase potential source compound and hides index and the quantitative relationship becoming to hide between probability;
Analytic unit 608, for hiding index and the quantitative relationship becoming to hide between probability according to the phase potential source compound control of setting up, hiding probability to the one-tenth of the lithologic deposit in described study area and analyzing.
In one embodiment, phase exponent calculation unit can calculate phase index in such a way: the porosity data and the permeability data that obtain described reservoir; Calculate relative porosity according to the porosity data obtained, calculate relative permeability according to the permeability data obtained; Phase index is calculated according to described relative porosity and relative permeability, wherein, can according to following formulae discovery relative porosity:
Φ
i＝Φ/Φ
max
Wherein, Φ represents reservoir porosity, Φ
maxrepresent the maximum reservoir porosity under same depth conditions, Φ
irepresent relative porosity;
According to following formulae discovery relative permeability:
K
i＝lg(K)/lg(K
max)
Wherein, K represents reservoir permeability, and unit is 10
-3μm
2, K
maxrepresent the maximum reservoir permeability under same depth conditions, unit is 10
-3μm
2, K
irepresent relative permeability;
Finally, according to described relative porosity and relative permeability according to following formulae discovery phase index:
FI＝(Φ
i+K
i)/2
Wherein, FI represents phase index, and value is 0 ~ 1, Φ
irepresent relative porosity, K
irepresent relative permeability.
In one embodiment, above-mentioned gesture exponent calculation unit can first according to following formulae discovery interface-potential;
Wherein, P represents interface-potential, and σ represents interfacial tension, and θ represents heterogeneous fluid contact angle, and r represents pore throat radius;
Then, according to following formulae discovery gesture index:
PI＝(P
s-P
min)/(P
max-P
min)
Wherein, PI represents gesture index, and value is 0 ~ 1, P
srepresent the interface-potential of reservoir self, P
minrepresent the interface-potential of the sandstone that pore throat radius under same Conditions of Buried Depth is maximum, P
maxrepresent the mud stone interface-potential under same Conditions of Buried Depth.
In one embodiment, above-mentioned phase gesture index of coupling computing unit can according to described phase exponential sum gesture index according to the following formulae discovery phase gesture index of coupling;
Wherein, FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, FI represents phase index, and PI represents gesture index.
In one embodiment, above-mentioned source control exponent calculation unit can control index according to following formulae discovery source:
Wherein, SI represents source control index, and value is 0 ~ 1, L
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to Pai Ting center, l
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to row hydrocarbon border, qe represents maximum row's hydrocarbon intensity of hydrocarbon source rock, and unit is 10
6t/km
2.
Wherein, above-mentioned standardized hydrocarbon-bearing pool can obtain according to following formulae discovery to the distance at Pai Ting center:
L
standardization=L/L
0
In one embodiment, above-mentioned standardized hydrocarbon-bearing pool can obtain according to following formulae discovery to the distance on row hydrocarbon border:
L
standardization=l/L
0
Wherein, L represents the distance of hydrocarbon-bearing pool to Pai Ting center, and l represents the distance of hydrocarbon-bearing pool to row hydrocarbon border, L
0represent along L direction, Pai Ting center is to the distance on row hydrocarbon border.
In one embodiment, exponent calculation unit is hidden in above-mentioned phase potential source compound control can hide index according to following formulae discovery phase potential source compound control:
FPSI＝(FPI+SI)/2
Wherein, FPSI represents that index is hidden in the control of phase potential source compound, and FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, SI represents source control index, and value is 0 ~ 1.
In each embodiment above-mentioned, lithologic deposit to be analyzed can be the hydrocarbon-bearing pool and the trap that falls through that have found in study area.
In another embodiment, additionally provide a kind of software, this software is for performing the technical scheme described in above-described embodiment and preferred implementation.
In another embodiment, additionally provide a kind of storage medium, store above-mentioned software in this storage medium, this storage medium includes but not limited to: CD, floppy disk, hard disk, scratch pad memory etc.
From above description, can find out, the embodiment of the present invention achieves following technique effect: first calculate phase index, gesture exponential sum source control index, then the phase gesture index of coupling is calculated according to phase exponential sum gesture index, calculate the control of phase potential source compound according to the phase gesture index of coupling and source control index and hide index, the last phase potential source compound control analyzing the lithologic deposit in multiple region to be analyzed is again hidden exponential sum and is become to hide probability, thus realize the analysis of hiding probability based on the one-tenth of the comprehensive lithologic deposit of phase potential source, thus solve and in prior art, probabilistic forecasting is hidden to the one-tenth of lithologic deposit and still rest on semidefinite quantization stage, the also technical matters of unrealized accurate quantitative examination, reach and the object that probability carries out quantitative examination is hidden to the one-tenth of lithologic deposit.
Obviously, those skilled in the art should be understood that, each module of the above-mentioned embodiment of the present invention or each step can realize with general calculation element, they can concentrate on single calculation element, or be distributed on network that multiple calculation element forms, alternatively, they can realize with the executable program code of calculation element, thus, they can be stored and be performed by calculation element in the storage device, and in some cases, step shown or described by can performing with the order be different from herein, or they are made into each integrated circuit modules respectively, or the multiple module in them or step are made into single integrated circuit module to realize.Like this, the embodiment of the present invention is not restricted to any specific hardware and software combination.
The foregoing is only the preferred embodiments of the present invention, be not limited to the present invention, for a person skilled in the art, the embodiment of the present invention can have various modifications and variations.Within the spirit and principles in the present invention all, any amendment done, equivalent replacement, improvement etc., all should be included within protection scope of the present invention.
Claims (10)
1. determine a method for lithologic reservoir forming probability, it is characterized in that, comprising:
According to porosity data and the permeability data of the reservoir of lithologic deposit to be analyzed in study area, calculate phase index;
According to pore throat radius data and the interfacial tension data of described reservoir, calculate gesture index;
Gesture index according to described phase exponential sum, calculates the phase gesture index of coupling;
Utilize the Distance geometry oil gas that the hydrocarbon source rock in described study area arranges hydrocarbon intensity, oil gas is hidden within Pai Ting center to be hidden within the distance of arranging hydrocarbon border, calculate source control index;
Utilize control index in source described in described phase index, described gesture exponential sum, calculate the control of phase potential source compound and hide index;
Repeat above-mentioned steps, index is hidden in the phase potential source compound control calculating each lithologic deposit in multiple lithologic deposit to be analyzed;
The one-tenth Tibetan probability multiple phase potential source compound controls obtained being hidden to each lithologic deposit to be analyzed of exponential sum is added up, and sets up the control of phase potential source compound and hides index and the quantitative relationship becoming to hide between probability;
Hide index and the quantitative relationship becoming to hide between probability according to the phase potential source compound control of setting up, probability is hidden to the one-tenth of the lithologic deposit in described study area and analyzes.
2. the method for claim 1, is characterized in that, according to porosity data and the permeability data of the reservoir of lithologic deposit to be analyzed in study area, calculates phase index, comprising:
Obtain porosity data and the permeability data of described reservoir;
Calculate relative porosity according to the porosity data obtained, calculate relative permeability according to the permeability data obtained;
Phase index is calculated according to described relative porosity and relative permeability.
3. method as claimed in claim 2, is characterized in that:
According to following formulae discovery relative porosity:
Φ
i＝Φ/Φ
max
Wherein, Φ represents reservoir porosity, Φ
maxrepresent the maximum reservoir porosity under same depth conditions, Φ
irepresent relative porosity;
According to following formulae discovery relative permeability:
K
i＝lg(K)/lg(K
max)
Wherein, K represents reservoir permeability, and unit is 10
-3μm
2, K
maxrepresent the maximum reservoir permeability under same depth conditions, unit is 10
-3μm
2, K
irepresent relative permeability;
According to described relative porosity and relative permeability according to following formulae discovery phase index:
FI＝(Φ
i+K
i)/2
Wherein, FI represents phase index, and value is 0 ~ 1, Φ
irepresent relative porosity, K
irepresent relative permeability.
4. the method for claim 1, is characterized in that, by described pore throat radius data and interfacial tension data, calculates gesture index, comprising:
According to following formulae discovery interface-potential;
Wherein, P represents interface-potential, and σ represents interfacial tension, and θ represents heterogeneous fluid contact angle, and r represents pore throat radius;
According to following formulae discovery gesture index:
PI＝(P
s-P
min)/(P
max-P
min)
Wherein, PI represents gesture index, and value is 0 ~ 1, P
srepresent the interface-potential of reservoir self, P
minrepresent the interface-potential of the sandstone that pore throat radius under same Conditions of Buried Depth is maximum, P
maxrepresent the mud stone interface-potential under same Conditions of Buried Depth.
5. the method for claim 1, is characterized in that, according to described phase exponential sum, gesture index is according to the following formulae discovery phase gesture index of coupling;
Wherein, FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, FI represents phase index, and PI represents gesture index.
6. the method for claim 1, is characterized in that, according to following formulae discovery source control index:
Wherein, SI represents source control index, and value is 0 ~ 1, L
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to Pai Ting center, l
standardizationrepresent the distance of standardized hydrocarbon-bearing pool to row hydrocarbon border, qe represents maximum row's hydrocarbon intensity of hydrocarbon source rock, and unit is 10
6t/km
2.
7. method as claimed in claim 6, is characterized in that:
The distance of standardized hydrocarbon-bearing pool to Pai Ting center is obtained according to following formulae discovery:
L
standardization=L/L
0
The distance of standardized hydrocarbon-bearing pool to row hydrocarbon border is obtained according to following formulae discovery:
L
standardization=l/L
0
Wherein, L represents the distance of hydrocarbon-bearing pool to Pai Ting center, and l represents the distance of hydrocarbon-bearing pool to row hydrocarbon border, L
0represent along L direction, Pai Ting center is to the distance on row hydrocarbon border.
8. the method for claim 1, is characterized in that, hides index according to following formulae discovery phase potential source compound control:
FPSI＝(FPI+SI)/2
Wherein, FPSI represents that index is hidden in the control of phase potential source compound, and FPI represents the phase gesture index of coupling, and value is that 0 ~ 1, SI represents source control index, and value is 0 ~ 1.
9. the method according to any one of claim 1 to 8, is characterized in that, described lithologic deposit to be analyzed is the hydrocarbon-bearing pool and the trap that falls through that have found in study area.
10. determine a device for lithologic reservoir forming probability, it is characterized in that, comprising:
Phase exponent calculation unit, for porosity data and the permeability data of the reservoir according to lithologic deposit to be analyzed in study area, calculates phase index;
Gesture exponent calculation unit, for according to the pore throat radius data of described reservoir and interfacial tension data, calculates gesture index;
Phase gesture index of coupling computing unit, for gesture index according to described phase exponential sum, calculates the phase gesture index of coupling;
Source control exponent calculation unit, for utilizing the Distance geometry oil gas that the hydrocarbon source rock in described study area arranges hydrocarbon intensity, oil gas is hidden within Pai Ting center to be hidden within the distance of arranging hydrocarbon border, calculates source control index;
Exponent calculation unit is hidden in the control of phase potential source compound, for utilizing control index in source described in described phase index, described gesture exponential sum, calculating the control of phase potential source compound and hiding index;
Repeat unit, for repeating above-mentioned steps, index is hidden in the phase potential source compound control calculating each lithologic deposit in multiple lithologic deposit to be analyzed;
Quantitative relationship determining unit, the one-tenth for hiding each lithologic deposit to be analyzed of exponential sum to the multiple phase potential source compound controls obtained is hidden probability and is added up, and sets up the control of phase potential source compound and hides index and the quantitative relationship becoming to hide between probability;
Analytic unit, for hiding index and the quantitative relationship becoming to hide between probability according to the phase potential source compound control of setting up, hiding probability to the one-tenth of the lithologic deposit in described study area and analyzing.
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