CN1015671B - Oil deposit-described method by earthquake date - Google Patents
Oil deposit-described method by earthquake dateInfo
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Abstract
The present invention relates to a method for describing oil reservoirs by seismic data, which mainly comprises the steps of the comprehensive analysis of the deposits and the structures of oil containing areas, the contrastive analysis of well logging data and rock core data, the determination of background rock character parameters of strata, the calculation of the residual acoustic impedance of strata, the analysis of speed components and density components of strata, the calculation of the apparent porosity of components and intersection, the comprehensive interpretation of rock characters, and the determination of the apparent porosity and the oil saturation of oil layers.
Description
The present invention relates to a kind ofly describe the method for oil reservoir with seismic data, the method is to use the earthquake sound impedance, and the factor of porosity and the oil saturation of oil reservoir are made quantitative estimation accurately.
At an area exploration hydrocarbon resources, drill a spot of prospect pit, and run into oil-bearing formation, in order to reach maximum benefit with minimum investment, before disposing development plan, will study this oil reservoir.Except the space distribution of determining oil reservoir, the more important thing is reservoir properties is studied, so just can make stock number estimation accurately and and guide exploitation.The research topic that reservoir description is risen at this purpose just, the present invention also provides a kind of like this method for reservoir description just.
Along with going deep into of degree of prospecting, the target of exploration becomes and becomes increasingly complex, and more is tending towards seeking elusive reservoir, has also produced many exploration new methods thereupon.After Pickett (picktt, 1963) proposes to use velocity of longitudinal wave and shear wave velocity, many new methods have been proposed in this regard, as BrP GB1,594,633; GB2,172,401A and U.S. Pat 4,373,197; US4,375,092; US4,554,649; US4,562,558 etc., some researchists such as Audi's top grade (Audet et al, 1982), many meters Nicos (Domenico, 1984) and Robert are inferior etc. (J.D.Robertson et al, 1985) has all published the achievement aspect integrated application Vp and Vs separately.Being tending towards proven technique at present then is amplitude and offset distance (AVO) technology and background normal component (Background Normal) method.In above-mentioned certain methods, in theory also there is query in some of them, such as the application problem of Vp/Vs ratio.And resembling the AVO technology, it utilized is that reflection coefficient increases with the increase of reflection angle on the bottom boundary of oil bearing reservoir top, has also just correspondingly formed the variation of echo amplitude with offset distance thereupon.It is effectively to the research of superficial part zone of interest, but the centering deep formation has run into some difficulties, because in a limited spread length, the incident angle that nearly offset distance geophone station and offset distance geophone station far away are accepted the deep reflex ripple changes not quite.
When people are deep day by day to the application of shear wave data, application to the earthquake conventional data but is tending towards backward relatively, particularly causes the influence factor and the Changing Pattern of petrophysical parameter variation from the angle research of geology (comprising petrology and mineralogy).Fortunately, many famous researchists have also delivered some important achievements in research in this regard, as (G.H.F.Gardner et al such as Gardners, 1974, Geophysics Vol 39, No6), with Gori (A.R.Gregory in passing, 1977, AAPG Memoir 26).On method, resemble interior Dorr (N.S.Neidell, 1985, AAPG Memoir 39), the SLIM method (1988 of Gu Dixi (T.Guidish) and Dubai you (M.Debuyl), Seismic Stratigraphy Atlas and J.Petr.Tech.Vol 40, No4) or the like.These theoretical and methods have all been set forth approach and restriction condition with the direct oil prospecting of seismic method from different angles.On method innovation, be still waiting further deeply.
The purpose of this invention is to provide a kind of for determining that oilfield development program describes the method for oil reservoir, this method also can be in exploration process oil reservoir prediction.Realize that the method invention is by after synthetic study is carried out on deposition, structure and the lithologic seismic basis in work area, use the earthquake sound impedance and determine lithology and quantitative estimation formation porosity and oil reservoir oil saturation.
The content of the method invention comprises geologic information analysis-by-synthesis (containing deposition and structure two parts), and its research range is decided according to the actual conditions in work area, must have certain mudstone sample to do the mudstone compacting analysis at least and come layer parameter definitely; Well-log information is proofreaied and correct, the contrast of theogram and seismic reflection time section; The well-log information after the correction and the comparative analysis of rock core information are with the conversion relation between the laboratory measurement parameter of the log parameter of determining subterranean strata and surface rock sample; Ask for stratum background velocity sequence and stratum background density sequence; Ask its stratum background sound impedance sequence again, and ask stratum residue acoustic impedance sequence; For the acoustic impedance on specific stratum, the stratum acoustic impedance is resolved into a formation velocity component and a density of earth formations component according to its layer position, place and the degree of depth (or TO).Equally, try to achieve one group of stratum residual velocity sequence and one group of stratum residual density sequence with formation velocity component and stratum background velocity and density of earth formations component and stratum background density.These stratum surpluses of integrated application are judged lithology.Judge that with dual porosity method the oil-containing water-based on stratum is to derive first visible porosity Φ av and another kind of method derives the second visible porosity Φ ap from the density of earth formations component with a kind of method from the formation velocity component, determines the oil-containing water-based on specific stratum with the intersection of these two kinds of visible porosities.For a specific stratum, determine the oil-containing water saturation degree with the plotted point of its dual porosity and the distance of reference curve or ratio K=(Φ av)/(the Φ ap) of two kinds of factor of porosity; Determine stratum (oil reservoir) factor of porosity according to the magnitude relationship of formation velocity component and density of earth formations component and K value again.
, formation pore big at formation porosity is when the output gas oil ratio in the saturated or hole is very high by gas, and the reaction of K value is more sensitive.
This method invention, integrated geology, prospecting geophysics and mineralogical method have avoided the simple data on the one hand of using to describe incomprehensive that oil reservoir brings.In the reservoir description at the scene, use the geological drilling data merely, can't make accurate estimation, cooperate deposition and tectonic analysis also just to come interpolation and extrapolation with researchist's experience to the extrapolation of horizontal change between well and well and wellbore.Merely using the prospecting geophysical method is method of seismic prospecting, be to start with mostly from petrophysical parameter, set up various mathematical models, perhaps use a small amount of lithologic analysis data, but also only relate to the extension on stratum, i.e. the physical property characteristic that the stratum showed, and lack intension to the stratum, be that the essence that the stratum has is furtherd investigate, only that is to say and just the secondary data of oil reservoir is studied with earthquake source investigation oil reservoir.Though can solve the horizontal change problem of oil reservoir to a certain extent, in the vertical or have shortcoming on the origin cause of formation; The simple field geophysics data of using, it is well-log information, can solve the longitudinal frame problem of oil reservoir, but be subjected to the restriction of logging instrumentation itself, it is horizontal detection degree of depth problem, though new methods such as cooperation dipmeter log can be made explanations to the stratum of wellbore certain limit, further extrapolation is also just with the imagination.
In exploration of oil and gas field, integrated application geology, earthquake and well-log information are art and the combining of technology, and the method is invented and accomplished this point just.The advantage of this method invention is: the first, and can not only make accurately oil reservoir and describing, but also its origin cause of formation is made corresponding explanation, this is that a kind of complete cause-effect relationship is perfect; The second, in the process that realizes this method invention, turn over same physical parameter, eliminated single and single use physical parameter bring error, make it more to approach underground truth; The 3rd, the function of formation velocity and density is regarded formation porosity respectively as in this method invention, soon formation porosity projects to respectively on factor of porosity-velocity plane and the factor of porosity-density plane with the variation of formation velocity and density of earth formations, this just can make the error of two kinds of method differentiate factor of porosity be able to complementation, and the calculating of factor of porosity is after oil saturation calculates, and this just makes again that the factor of porosity of estimation is more accurate; The 4th, this method invention can not only be applied to known zone and describe oil reservoir, and can also be applied to the unknown area oil reservoir prediction; The 5th, the invention of this method can also provide the relation of a regional earthquake whilst on tour and the degree of depth, when lacking VSP and well-shooting data, can with it do time section of earthquake the time change deeply and well-log information is tentatively proofreaied and correct; The 6th, the method invention is established one's own system, and directly starts with from primary seismic wave reflection data, need not cooperate the shear wave data, and this has just been avoided gathering trouble and the investment increase that the shear wave data is brought.
The description of the drawings:
Fig. 1 is a workflow diagram of implementing this method invention.
Fig. 2 be a field area stratum background velocity Vpb and the time dark graph of a relation, ordinate is that seismic event two-way time TO(is unit with the second), the top margin abscissa is depth of stratum H scale (is unit with the kilometer), the base abscissa is that stratum background velocity Vpb(is unit with the kilometer per second), curve 1 is the stratum background velocity, curve 2 is the time dark relation curves of being derived by curve 1, dark relation curve when curve 3 is VSP first arrivals of this district's a bite well.
Fig. 3 is the relation curve of a field area seismic event two-way time T0 and stratum background velocity Vpb, stratum background density ρ b and stratum background sound impedance Z b.Ordinate is represented two-way time T0, and the top margin abscissa is represented stratum background velocity scale, and the two rows number under the abscissa of base is represented stratum background density and stratum background sound impedance scale respectively.Curve 1 is stratum background sound impedance, and curve 2 is the stratum background velocity, and curve 3 is the stratum background density.
Fig. 4,6,8th, the seismic event two-way time respectively with stratum acoustic impedance Z, the scatter diagram of formation velocity Vp and density of earth formations ρ relation.Ordinate is that T0(is unit with the second), abscissa is respectively the stratum acoustic impedance, formation velocity and density of earth formations have added stratum background sound impedance curve respectively among the figure, stratum background velocity curve and stratum background density curve.Symbol: O represents oil-bearing sand, and S represents water bearing sand, and H represents mud stone.
Fig. 5,7,9, be that the seismic event two-way time remains acoustic impedance Zr with the stratum respectively, the scatter diagram of stratum residual velocity Vpr and stratum residual density ρ r relation.Ordinate is that T0(shows with stopwatch), abscissa is respectively stratum residue acoustic impedance, stratum residual velocity and a stratum residual density.Be equivalent to respectively the stratum background sound impedance curve among Fig. 4, stratum background velocity curve among Fig. 6 and the stratum background density curve among Fig. 8 pull into vertical line.Symbol: O represents oil-bearing sand, and S represents water bearing sand, and H represents mud stone.
Figure 10 is the diffusing some X plot of density of earth formations ρ and formation velocity 1/Vp reciprocal, and symbol: O represents oil-bearing sand, and S represents water bearing sand, and H represents mud stone.
Figure 11 is the illustraton of model of factor of porosity Φ and formation velocity Vp and density of earth formations ρ relation.
Figure 12 is difference factor of porosity D Φ (density lead factor of porosity deduct speed lead factor of porosity) and the model of formation porosity Φ relation.Four curves represent that from bottom to top oil saturation So is respectively 25%, 50% among the figure, 75% and 100% situation.
Figure 13 is that speed is led the X plot that factor of porosity Φ av and density are led factor of porosity Φ a ρ.Abscissa is that density is led factor of porosity, and ordinate is that speed is led factor of porosity.Symbol: O is an oil-bearing sand, and S is a water bearing sand, and H is a mud stone; To be divided into five parts in the figure by the solid line at the defined diagonal angle of K=Φ av/ Φ a ρ and three adjacent dotted lines, and define this five districts: 1 district is the reservoir parameter distributive province; 2 districts are wet oil layer parameter distributive province; 3 districts are oil-containing water layer parameter distributive province; 4 districts are the aquifer parameter distributive province; 5 districts are the mudstone parameter district.
Figure 14 be by real data respectively from the acoustic impedance of earthquake differentiate with from the comparison diagram (left hurdle) of the acoustic impedance of well logging differentiate with respectively from the comparison diagram (right hurdle) of the factor of porosity of the factor of porosity of earthquake differentiate and well logging differentiate, its ordinate is that seismic event two-way time T0(unit is second).Hurdle, left side abscissa is an acoustic impedance, and right hurdle abscissa is a factor of porosity, and solid line is the parameter of earthquake differentiate, and dotted line is the parameter of well logging differentiate.
With a programmable microcomputer and plotting apparatus, can arbitrarily calculate and these maps of compilation and other additional map according to concrete needs.
The application of this method invention is implemented by workflow shown in Figure 1.
In fact, before setting about reservoir description, the explore aspect has been done a large amount of geological analysis work, and the enforcement of this method can be inherited previous work, but previous work must include to the mudstone compacting rule research of deposition, tectonic association relation etc.; Well-log information and rock core information comparative analysis at first are that the acoustic velocity data is proofreaied and correct, and do contrast with the core analysis data again.The technical essential of acoustic velocity data correction and requirement, be with acoustic velocity data and density data theogram after proofreading and correct, compare with the offset well seismic trace, proofread and correct log parameter theogram more repeatedly, till making it to reach satisfied coincideing with real seismic record.Distinguish several like this notions about factor of porosity; The rock surface net porosity, the rock surface total porosity, the underground net porosity of rock, the underground total porosity of rock, sonic porosity and density porosity are understood fully the mutual relationship between them.This analyzes and also relates to the use high-voltage physics data.
From the definition of lithology, lithology is to mineral assemblage in the rock, the research of rock type, and for reservoir study, it also should comprise the factor of porosity of rock, physical parameters such as oil saturation and permeability.
Rock type, factor of porosity and oil saturation are that subsurface formations exists the essence had, and speed and density or the acoustic impedance physical features that to be the stratum show.The factor that influences these physical parameters is a lot, and some factor is mutual association.Therefore, speed and density or acoustic impedance are not unique (or mutually contrast) to separating of lithology.So, eliminate certain influence factor after, speed and density or acoustic impedance have just reflected the variation of lithology.For this reason, after deriving, the present invention proposes by following equation:
dV/dt＝BV
2（1-V/Vm） （1）
dρ/dt＝BV（ρm-ρ） （2）
Find the solution stratum background velocity Vpb and stratum background density ρ b, and obtain stratum background sound impedance Z b by them.
Solving equation 1 obtains stratum background velocity sequence, has represented this curve (curve 1) variation in downward 2.5 seconds these seismic travel time sections in the face of land in Fig. 2.And by this curve to time integral, obtain a curve (curve 2), i.e. the relation curve of earthquake whilst on tour and the degree of depth, this curve almost completely overlaps with the VSP first arrival time-depth curve (curve 3) of respective depth (time) section a bite well.Therefore, Fig. 2 explanation, it is reliable that equation 1 is found the solution stratum background velocity sequence.
Fig. 3 has shown somewhere one particular studies interval (T0 was from 1.4 seconds-2.4 seconds) stratum background velocity, the Changing Pattern of stratum background density and stratum background sound impedance.Stratum background velocity sequence (curve 2) and stratum background density sequence (curve 3) all are with method of finite difference difference solving equation 1 and equation 2 gained, and stratum background sound impedance sequence then is by asking the long-pending of stratum background velocity sequence and stratum background density sequence to obtain.
The area that the invention of this method is tested has characteristics that are different from other exploratory area, promptly the acoustic impedance of mud stone below certain degree of depth apparently higher than the acoustic impedance of sandstone.Show that through mineralogical analysis mud stone is basically by illite (ρ: 2.64-3.0g/cm
3, V=6000m/s) form, and do not find the smectite of low-density and low velocity.Experimental analysis shows that the skeletal density of mud stone is ρ msh=2.729g/cm
3, the skeletal density of sandstone is ρ mss=2.724g/cm
3; This numerical value of sandstone is a little more than the density 2.65g/cm of quartz
3, this is because contain some other high density mineral in the sandstone; The matrix velocity of mud stone is 6024m/s; The matrix velocity of sandstone is 5882m/s.Because sandstone does not satisfy the rule of the normal compacting of mud stone, sandstone porosity generally is higher than mudstone porosity, this rule of mud stone acoustic impedance apparently higher than the sandstone acoustic impedance also just occurred again.
Fig. 4 to Fig. 9 shown respectively seismic event two-way time T0 from 1.4 seconds to 2.4 seconds the acoustic impedance of 188 sampling points in the scope, the residue acoustic impedance, interval velocity, residual velocity, the regularity of distribution of density and residual density, and added stratum background sound impedance curve in the drawings respectively, and stratum background velocity curve and stratum background density curve, these three curves can be regarded acoustic impedance, speed and the density of sand, the mud stone division boundary with change in depth respectively as.The making of these maps is very simple, if can be just more convenient by a programmable calculator and plotting apparatus.At Fig. 4, after Fig. 6 and Fig. 8 compilation, can judge lithology according to the position that parameter point falls into picture frame, this position is a reference parameter point and the relative distance of background curves.This method invention, this three background curves not only are provided, and utilize these three background curves calculating reference points and their distance to calculate the stratum rest parameter just, utilize these rest parameters, just can directly judge lithology with their numerical value, these parameters have been eliminated the influence of the degree of depth (comprising association factors such as compacting, stratum age, ground temperature), have reflected the rule of lithology itself basically.
In these parameters, what density of earth formations reflected is the rock total porosity, it is not subjected to the influence of pore texture and rock crack basically, and that formation rock speed is influenced by the crack is bigger, and the effect of this influence is also very complicated, equally be subjected to the influence of the pore texture of open pore, but it is not influenced by the dissolution porosity of rock yet.When using log parameter to analyze, the actual measurement log parameter also has than mistake.The source of these errors can be divided three classes again, and error of first kind is that the complexity by borehole condition causes, comprises the uncontinuity of well, and is irregular as the borehole wall, alteration, clay swelling, formation anisotropy, bed boundary and crack etc. that mud immerses; Error of the second kind comprises measuring equipment itself and environmental impact; Error of third-kind-type then is to be caused by used evaluation method and randomness.Therefore, must carry out integrated calibration, eliminate the false and retain the true, they could be summed up rule, and this rule is applied to processing of seismic data and explanation log parameter.
The parsing of formation velocity component and density component is a function of formation velocity being regarded as background sound impedance and residue acoustic impedance, and promptly V=f(Zb Zr), tries to achieve the density of earth formations component with ρ=Z/V again.With acoustic impedance and residue acoustic impedance resolution speed component is to use following formula:
V=k
1Zb+k
2Zr+k
3R+k
4R=Zr/(Zb+Zr wherein)
Real data is carried out regression fit.K wherein
1, k
2, k
3, k
4Be constant.
Speed is led factor of porosity and density, and to lead factor of porosity be to use the rough estimation of two kinds of parameters to factor of porosity respectively, and these two kinds of factor of porosity all are visible porosities, and it is to think all saturated by local water in the formation pore.Because these two kinds of meaning differences that visible porosity reflected, when the water in the hole of stratum was partly replaced by oil or gas, they difference will occur, and this species diversity obviously strengthens with the increase of the increase of factor of porosity and oil saturation and gas hydrocarbon.Figure 10 as abscissa, carries out intersection to density of earth formations to the inverse of formation velocity as ordinate, can see that therefrom oil-bearing sand and mud stone concentrate on two bands significantly and distribute, and the centre is separated by a water bearing sand band.The ribbon distribution that also can see oil-bearing sand from figure is not really concentrated, and this is that the oil-gas ratio in oil saturation and the hole is decentralized this band owing to the oil-sand factor of porosity.
Figure 12 has adopted the basic parameter in a certain area, utilization supposes that with a kind of rock skeleton parameter factor of porosity changes to 30% from zero, and the water in the hole has 25% respectively, the Changing Pattern (rules of two kinds of visible porosity variations) of 50%, 75% and 100% this species diversity factor of porosity when being replaced by oil.Its explanation, along with the increase of factor of porosity and the increase of oil saturation, the difference of these two kinds of visible porosities increases.
Figure 13 is the X plot of these two kinds of factor of porosity, and it is that the visible porosity that is derived by density is treated as abscissa, and the factor of porosity that speed derives is treated as ordinate.As can be seen from the figure: water bearing sand is distributed near the diagonal line (slope k=Φ av/ Φ a ρ=1) that is equated to be connected by two kinds of visible porosities basically.Get k=Φ av/ Φ a ρ, equal 0.75 with k; 0.89; 1.00 with four straight lines of 1.20 map sheet is divided into five districts, sees the explanation of accompanying drawing 13.
Can make oil, water to the stratum, do the qualitative interpretation of layer according to lithology integrated interpretation and two kinds of visible porosities and their ratio.Concrete boundary is according to the real data of describing the district and require formulation.
Oil saturation is regarded as by speed and is led the function that factor of porosity and density are led the factor of porosity ratio k, increases with the k value, and oil saturation reduces, and reduces with k value, and oil saturation increases, and when the k value more than or equal to 1 the time, it is zero defining oil saturation.This method invention provides uses following formula:
So＝C（1-k） （k＝Φav/Φaρ，k＜1）
So＝0 （k≥1）
Find the solution oil saturation.Constant C in the formula is asked for by the match of real data and formula.
After asking for stratum oil saturation So, then can utilize following formula to ask for porosity value accurately:
Φ1＝ (1/V-1/Vm)/(So/Vo+（1-So）/Vw-1/Vm) （5）
Φ2＝ (ρ-ρm)/(Soρo+（1-So）ρw-ρm) （6）
Φ＝AΦ1+BΦ2 （7）
Wherein: V, Vm, Vo, Vw are respectively the speed of reservoir, matrix velocity, the speed of oil and the speed of water in the hole; ρ, ρ m, ρ o, ρ w is respectively the density of reservoir, skeletal density, the density of oil and the density of water in the hole; So is an oil saturation; Φ 1, and Φ 2 and Φ are respectively the two kinds of rough factor of porosity and the accurate factor of porosity of speed and density differentiate; A, B are respectively the weighting coefficient of two kinds of rough factor of porosity.
Formula 7 is when error analysis, demarcates calculating porosity value, selects the weighting coefficient of Φ 1 and Φ 2 respectively, makes it to calculate factor of porosity and reaches best unanimity.
So far, just finish the method and invented the overall process of describing oil reservoir with seismic data.
This method invention is applicable to that the area on section plane of sand shale stratum is used for known oil reservoir is described, and also can be used in the unknown area oil reservoir be predicted.
The employed seismic data of application requirements of the method invention is through three complete high processing.
The method working of an invention can be weaved into one or several module and directly finish on acoustic impedance section achievement band, imports corresponding formation parameter and processing parameter in the time of need only handling.
Claims (14)
1, a kind ofly describe the method for oil reservoir, it is characterized in that this method comprises following step with seismic data:
A. use the compaction coefficient B and the matrix velocity Vm of ground mfs layer to ask for stratum background velocity Vpb;
B. use the compaction coefficient B of ground mfs layer, speed and skeletal density are asked for stratum background density ρ b;
C. use Vpb and ρ b to ask for stratum background sound impedance Z b;
D. use formation velocity Vp and stratum background velocity Vpb to ask for stratum residual velocity Vr;
E. use density of earth formations ρ and stratum background density ρ b to ask for stratum residual density pr;
F. use stratum acoustic impedance Z and stratum background sound impedance Z b to ask for stratum residue acoustic impedance Zr;
G. use stratum background sound impedance Z b and stratum residue acoustic impedance Zr to ask for formation velocity component V;
H. use formation velocity component V and stratum acoustic impedance Z to ask for density of earth formations component ρ;
I. use the formation velocity component to ask for the first visible porosity Φ av;
J. use the density of earth formations component to ask for the second visible porosity Φ a ρ;
K. use the first visible porosity Φ av and the second visible porosity Φ a ρ to carry out intersection;
L. use the first visible porosity Φ av and the second visible porosity Φ a ρ to ask for oil reservoir oil saturation So;
M. use formation velocity component V, density of earth formations component ρ and oil saturation So to ask for the accurate factor of porosity Φ in stratum.
2, method according to claim 1 is characterized in that wherein among the step a: for differential equation dVpb/dt=B * Vpb(1-Vpb/Vm) at least a solution is obtained stratum background velocity Vpb.When wherein t is the seismic event outward journey.
3, method according to claim 1 is characterized in that wherein among the step b: for differential equation d ρ b/dt=B * Vpb(ρ m-ρ b) at least a solution obtains stratum background density ρ b.When wherein t is the seismic event outward journey.
4, method according to claim 1 is characterized in that wherein among the step c: Zb=Vpb * ρ b.
5, method according to claim 1 is characterized in that wherein in the steps d: Vr=Vp-Vpb.
6, method according to claim 1 is characterized in that wherein among the step e: ρ r=ρ-ρ b.
7, method according to claim 1 is characterized in that wherein among the step f: Zr=Z-Zb.
8, method according to claim 1 is characterized in that wherein in the step g:
V＝K
1×Zb+K
2×Zr+K
3×R+K
4。Here K
1, K
2, K
3, K
4Be constant, R=Zr/(Zb+Zr).
9, method according to claim 1 is characterized in that wherein among the step h: ρ=Z/V.
10, method according to claim 1 is characterized in that wherein in the step I: rely at least a method to ask for the first visible porosity Φ av from formation velocity component V.
11, method according to claim 1 is characterized in that wherein among the step j: rely at least a method to ask for the second visible porosity Φ a ρ from density of earth formations component ρ.
12, method according to claim 1, it is characterized in that wherein among the step k: Φ av is put on an axis, and Φ a ρ is placed on and carries out intersection on another axis.
13, method according to claim 1 is characterized in that wherein among the step l:
a.K＝Φav/Φap。Here K is the oil reservoir coefficient;
b.So＝0（K≥1），So＝C（1-K）（K＜1）。Here C is a constant.
14, method according to claim 1 is characterized in that wherein among the step m:
A. use formation velocity component V and oil saturation So to ask for the first rough factor of porosity Φ 1;
B. use density of earth formations component ρ and oil saturation So to ask for the second rough factor of porosity Φ 2;
C. Φ=A * Φ 1+B * Φ 2, A and B are weighting coefficients here, its value is constant.
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN 90104152 CN1015671B (en) | 1990-06-09 | 1990-06-09 | Oil deposit-described method by earthquake date |
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|---|---|---|---|
| CN 90104152 CN1015671B (en) | 1990-06-09 | 1990-06-09 | Oil deposit-described method by earthquake date |
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| CN1015671B true CN1015671B (en) | 1992-02-26 |
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Families Citing this family (7)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN100349006C (en) * | 2004-12-29 | 2007-11-14 | 中国石油天然气集团公司 | Method for determining distribution of lithologic character and liquid by using inversion technique of wave impedance |
| CN101446645B (en) * | 2007-11-27 | 2011-08-03 | 中国石油天然气股份有限公司 | Method for determining fluid by utilizing seismic fluid impedance |
| CN101183154B (en) * | 2007-11-30 | 2010-04-07 | 辽河石油勘探局 | Geological logging explanation evaluating method |
| CN101625420B (en) * | 2009-07-22 | 2012-05-09 | 中国石化集团胜利石油管理局 | Reservoir description method |
| CN103116186B (en) * | 2011-11-16 | 2015-08-19 | 中国石油天然气集团公司 | A kind of volume defining method of small scale heterogeneous body Reservoir Body |
| CN103206207B (en) * | 2013-03-01 | 2015-06-17 | 陕西延长石油(集团)有限责任公司研究院 | Favorable oil reservoir region identification method based on hydrocarbon generation period ancient structure |
| CN105370274B (en) * | 2015-12-14 | 2018-08-21 | 长江大学 | Down-hole formation porosity determines method |
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1990
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