CN113719277A - Calculation method for water saturation of low-permeability reservoir - Google Patents
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 69
- 238000004364 calculation method Methods 0.000 title description 19
- 239000008398 formation water Substances 0.000 claims abstract description 55
- 239000011435 rock Substances 0.000 claims abstract description 54
- 238000000034 method Methods 0.000 claims abstract description 37
- 229920006395 saturated elastomer Polymers 0.000 claims abstract description 33
- 239000011148 porous material Substances 0.000 claims abstract description 13
- 239000011159 matrix material Substances 0.000 claims description 11
- 238000002474 experimental method Methods 0.000 claims description 7
- 238000002922 simulated annealing Methods 0.000 claims description 6
- 238000011161 development Methods 0.000 abstract description 8
- 230000000694 effects Effects 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 20
- 239000012530 fluid Substances 0.000 description 5
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- 230000015572 biosynthetic process Effects 0.000 description 2
- 238000005755 formation reaction Methods 0.000 description 2
- 239000008161 low-grade oil Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- NAWXUBYGYWOOIX-SFHVURJKSA-N (2s)-2-[[4-[2-(2,4-diaminoquinazolin-6-yl)ethyl]benzoyl]amino]-4-methylidenepentanedioic acid Chemical compound C1=CC2=NC(N)=NC(N)=C2C=C1CCC1=CC=C(C(=O)N[C@@H](CC(=C)C(O)=O)C(O)=O)C=C1 NAWXUBYGYWOOIX-SFHVURJKSA-N 0.000 description 1
- 238000009933 burial Methods 0.000 description 1
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- 238000009795 derivation Methods 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 239000004973 liquid crystal related substance Substances 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
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- 238000006467 substitution reaction Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
- G06F17/10—Complex mathematical operations
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
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Abstract
The invention discloses a method for calculating the water saturation of a hypotonic reservoir, which comprises the following steps: obtaining the resistivity of the argillaceous and formation water, parameters reflecting the structure and connectivity of a rock reservoir, the conductivity of saturated rocks, the porosity of connected pores, the total porosity and the argillaceous content; counting the ratio of the movable formation water volume to the immobile formation water volume in the reservoir; and calculating the water saturation of the reservoir according to the obtained parameters. The method is based on the effective medium conduction theory, establishes a saturated rock model of the low-permeability reservoir, deduces the relation between the resistivity and the water saturation of the saturated rock, and effectively improves the prediction precision of the water saturation of the low-permeability reservoir. The method can be applied to identification of oil and water layers of a low-permeability reservoir, and has important significance for optimizing a perforation well section, effectively avoiding water development and improving the development effect.
Description
Technical Field
The invention relates to the field of petroleum logging engineering, in particular to a calculation method for water saturation of a hypotonic reservoir.
Background
In general, the fluid saturation can be expressed by the Archie's empirical formula, but the Archie's formula applies to conditions of simple porosity in pure sandstone. As oil field exploration and development continues to advance, the goals of oil field exploration and development have shifted towards low-grade oil reservoirs. The low-grade oil reservoir generally has the characteristics of low porosity, low permeability, compact reservoir and the like, the conductivity law of reservoir rock under the complex geologic body condition is greatly different from the conductivity law of conventional reservoir resistance, and the non-Archie relationship is obvious. The oil layer is difficult to accurately identify, dynamic and static data are not matched, geology is not known clearly, and great difficulty is caused to the increasing, storing and building of the oil deposit.
Disclosure of Invention
The invention aims to provide a calculation method for the water saturation of a hypotonic reservoir, which can effectively improve the calculation precision compared with an Archie formula.
In order to achieve the purpose, the invention adopts the following technical scheme:
the invention provides a method for calculating the water saturation of a hypotonic reservoir, which comprises the following steps:
s100, obtaining the resistivity of argillaceous and formation water, parameters reflecting the structure and connectivity of a rock reservoir, the conductivity of saturated rock, the connected porosity, the total porosity and the argillaceous content; counting the ratio of the movable formation water volume to the immobile formation water volume in the reservoir;
and S200, calculating the water saturation of the reservoir according to the obtained parameters.
According to the calculation method for the water saturation of the hypotonic reservoir, S100 preferably specifically includes:
obtaining the resistivity of the argillaceous and formation water and parameters reflecting the structure and connectivity of a rock reservoir according to a laboratory core physical experiment;
according to the observation of the core slice, the ratio of the volume of movable formation water to the volume of immobile formation water in the reservoir is counted;
obtaining the conductivity of the saturated rock according to the resistivity of the saturated rock in the logging data;
obtaining the connected porosity by using acoustic logging data;
obtaining total porosity using density log data;
and obtaining the shale content by utilizing natural gamma logging data.
According to the calculation method for the water saturation of the hypotonic reservoir, the parameters reflecting the rock reservoir structure and the connectivity preferably comprise lambdash、γwl、γsh、γwl、γo；
Lambda and gamma are component characteristic parameters, lambda reflects the connectivity of the component, and gamma reflects the shape and structure of the component; subscripts sh, o, wl denote shale, oil, mobile formation water, respectively.
According to the calculation method of the water saturation of the hypotonic reservoir, the water saturation S is preferably calculated in S200 by utilizing a rapid simulated annealing methodwSubstituted into the model in the interval [0,1]]Carrying out iterative solution to calculate the water saturation of the reservoir; when S iswWhen the content is 1, the water content is 100 percent, and pure water is filled in pores and is a water layer; swWhen 0 is assumed (theoretically), the water content is 0, and the pores are pure oil and pure oil layers. Normal subsurface oil formations contain water, and water formations may be free of oil, so Sw is often (0,1)]。
The model is as follows:
φm+Vsh+φaas 1 type (8)
φa＝φo+φw＝φo+φwl+φwsFormula (9)
Wherein C is the conductivity, CtConductivity of saturated rock in units of S/m;
phi is the volume fraction of each component, and the value range is (0, 1); phi is aeIs connected with the porosity of the pores and has a value of phie＝φo+φwl；φaIs the total porosity;
n is the ratio of the movable formation water volume to the immobile formation water volume in the reservoir;
lambda and gamma are component characteristic parameters, and the value ranges are [0,1 ]; λ reflects the connectivity of the component, γ reflects the shape and structure of the component;
Vshthe values are all [0,1] for the argillaceous content]；
Subscripts sh, o, wl, ws, m, w represent argillaceous, oil, mobile formation water, immobile formation water in the microporosity, matrix framework, and formation water, respectively.
According to the method for calculating the water saturation of the hypotonic reservoir, the conductivity of the saturated rock is preferably calculated by the formula (16):
wherein R istThe resistivity of the saturated rock is in units of omega meters; ctIs the conductivity of saturated rock in units of S/m.
According to the method for calculating the water saturation of the hypotonic reservoir, the connected porosity phi is preferably obtainedeTotal porosity phiaMud content VshPhi is obtained by the following formulam、φo、φwl、φws：
φm＝1-Vsh-φa，φo＝(1-Sw)φa，φwl＝φe-(1-Sw)φa，φws＝φa-φe；
And use itDirect substitution into formula (12) of water saturation SwIn the formula (12), in the interval [0,1]]And carrying out iterative solution to calculate the water saturation of the reservoir.
According to the method for calculating the water saturation of the hypotonic reservoir, the method for calculating the water saturation of the hypotonic reservoir preferably comprises the following steps:
s100, obtaining the resistivity C of the muddy and formation water according to the physical experiment of the laboratory rock coresh、CwlAnd a parameter λ reflecting the rock reservoir structure and connectivitysh、λwl、γsh、γwl、γo；
According to the observation of the core slice, counting the volume ratio n of movable formation water to immobile formation water in the reservoir;
from the saturated rock resistivity R in the log datatObtaining the conductivity C of the saturated rockt；
Obtaining connected porosity phi from sonic logging dataeAnd has a diameter ofe＝φo+φwl；
Obtaining total porosity phi from density log dataa；
Obtaining the mud content V by using natural gamma well logging datash；
S200, substituting the water saturation Sw into the model by using a rapid simulated annealing method, carrying out iterative solution between intervals [0,1], and calculating the water saturation of the reservoir stratum;
the model is as follows:
φm+Vsh+φaas 1 type (8)
φa＝φo+φw＝φo+φwl+φwsFormula (9)
Wherein C is the conductivity, CtConductivity of saturated rock in units of S/m;
phi is the volume fraction of each component, and the value range is (0, 1); phi is aeIs connected with the porosity of the pores and has a value of phie＝φo+φwl；φaIs the total porosity;
n is the ratio of the movable formation water volume to the immobile formation water volume in the reservoir;
lambda and gamma are component characteristic parameters, and the value ranges are [0,1 ]; λ reflects the connectivity of the component, γ reflects the shape and structure of the component;
Vshthe values are all [0,1] for the argillaceous content]；
Subscripts sh, o, wl, ws, m, w represent argillaceous, oil, mobile formation water, immobile formation water in the microporosity, matrix framework, and formation water, respectively.
According to the method for calculating the water saturation of the hypotonic reservoir, the connected porosity phi is preferably obtainedeTotal porosity phiaMud content VshPhi is obtained by the following formulam、φo、φwl、φws：
φm＝1-Vsh-φa，φo＝(1-Sw)φa，φwl＝φe-(1-Sw)φa，φws＝φa-φe；
And directly substituting the water saturation into the formula (12) to obtain the water saturation SwIn the formula (12), in the interval [0,1]]And carrying out iterative solution to calculate the water saturation of the reservoir.
According to the calculation method of the water saturation of the hypotonic reservoir, S is preferably ledwAt (0.33,1]Optimizing within the range. The unit volume of a rock is 1, phia+Vsh+φm1, any value therein being only>0 has a physical meaning, so in the example application, phiwl＝0.144Sw-0.048>0, result in SwGreater than 0.33.
According to the calculation method for the water saturation of the hypotonic reservoir, the objective function is preferably satisfied during iterative solution
I.e. stopping iteration to obtain the optimal solution. More preferably still, the first and second liquid crystal compositions are,
the iteration is stopped, the convergence precision is better and the calculation time is shorter.
In the practical application process, the rock physical experiment is utilized to determine the structure and connectivity parameters of the rock, and the new calculation model is utilized to calculate the water saturation of the reservoir stratum. Compared with an Archie formula, the method effectively improves the calculation precision.
Specifically, the derivation process of the calculation model of the invention is as follows:
according to the effective medium symmetric conduction theory, the conductivity of the saturated rock is as follows (1):
wherein N is the component number contained in the saturated rock; c is the conductivity, the unit of S/m is the reciprocal of the resistivity; subscripts sat, i represent saturated rock and ith component, respectively; phi is aiIs the volume fraction of the ith component; cogIs represented by formula (2):
lambda and gamma are characteristic parameters of the components, lambda reflects connectivity of the components, and gamma reflects the shape and structure of the components.
For aqueous pure sandstone, the saturated rock is composed of sandstone matrix skeleton and aqueous pores, and the conductivity is as the following formula (3) and formula (4):
wherein the subscripts m, w represent the matrix skeleton and formation water, respectively.
Since the rock is composed of only water-containing pores and a sandstone matrix skeleton, the rock has the formula (5):
φm+φwas 1 type (5)
Sandstone matrix skeleton is not conductive, therefore C m0; at the same time for homogeneous rocks, there is γm＝γw. Then formula (6) and formula (7):
the development of mud and microporosities in a hypotonic reservoir is compared, and the complex pore structure characteristics and fluid properties have an influence on the conductivity of saturated rocks. Different from a sandstone matrix skeleton, the surface of mudstone particles is easy to absorb ion minerals and has certain conductivity. Meanwhile, due to the influence of dispersed argillaceous substances in a reservoir, the communication performance among micropores is poor, the fluid fluidity is low, an effective migration channel is not formed in the oil and gas migration process, and formation water in the micropores is not displaced. This makes it possible to obtain formulae (8) and (9):
φm+Vsh+φaas 1 type (8)
φa＝φo+φw＝φo+φwl+φwsFormula (9)
Wherein, VshSubscripts a, o, w for the shale content of the saturated rockl、wsRespectively, total pore, oil, mobile formation water, and immobile formation water in the micropores.
Substituting formula (8) and formula (9) into formula (1) to obtain formula (10):
taking into account the conductivity properties of the components, Cm＝C o0; since microporosities are not connected, C ws0; to obtain formula (11):
the formula (11) is arranged to obtain a formula (12):
simultaneously, the communicating pores distributed in the matrix skeleton are filled with oil and movable formation water to obtain gammao＝γwl，λm≈λo＝λwl(ii) a Substituted into formula (2), there is formula (13):
the production of the hypotonic reservoir layer needs fracturing modification, and the micropores are communicated through a fracturing process, so that the seepage capability of fluid is improved; thus water saturation S for hypotonic reservoirswIs of formula (14):
assuming a ratio n of movable formation water to immobile formation water volume in a reservoir; then formula (14) is formula (15):
the saturated rock resistivity is R through resistivity loggingtConductivity of saturated rock CtIs of formula (16):
therefore, the calculation model obtained by the invention is as follows:
φm+Vsh+φaas 1 type (8)
φa＝φo+φw＝φo+φwl+φwsFormula (9)
Wherein C is the conductivity, CtConductivity of saturated rock in units of S/m;
phi is the volume fraction of each component; phi is aeIs connected with the porosity of the pores and has a value of phie＝φo+φwl；φaIs the total porosity;
n is the ratio of the movable formation water volume to the immobile formation water volume in the reservoir;
lambda and gamma are component characteristic parameters, lambda reflects the connectivity of the component, and gamma reflects the shape and structure of the component;
Vshis the mud content;
subscripts sh, o, wl, ws, m, w represent argillaceous, oil, mobile formation water, immobile formation water in the microporosity, matrix framework, and formation water, respectively.
The () or [ ] sign in the value range involved in the present invention has no essential difference, because the value generally does not reach the limits of both sides in the actual calculation.
The water saturation of the reservoir can be directly calculated by utilizing the model according to rock physical experiments, various logging data and the like; compared with an Archie formula, the method effectively improves the calculation precision.
The method is based on the effective medium conduction theory, establishes a saturated rock model of the low-permeability reservoir, deduces the relation between the resistivity and the water saturation of the saturated rock, and effectively improves the prediction precision of the water saturation of the low-permeability reservoir. The method can be applied to identification of oil and water layers of a low-permeability reservoir, and has important significance for optimizing a perforation well section, effectively avoiding water development and improving the development effect.
Drawings
FIG. 1 is a plot A well log data and reinterpretation results in an embodiment of the present invention.
Detailed Description
In order to more clearly illustrate the invention, the invention is further described below in connection with preferred embodiments. It is to be understood by persons skilled in the art that the following detailed description is illustrative and not restrictive, and is not to be taken as limiting the scope of the invention.
The invention provides a specific application example, and the storage conditions are as follows:
the large-depression oil field is double 229 blocks, the oil-gas-containing layer is a sand section, the oil reservoir burial depth is 3100-. Determining lambda according to the rock core experiment data of the exploratory wellsh＝0.82，λwl＝0.27，γsh＝0.75，γwl＝0.22，γo＝0.18。
As shown in figure 1, in No. 36 layers of depression A wells 3549.8-3554.3 well sections, the sound wave time difference is 77.2ms/m, and the density is 2.41g/cm3The deep lateral resistivity is 11.2 omega.m, the natural gamma is 61.1API, the water saturation is 99.4 percent by utilizing the Archie's formula, the saturation is explained as an oil-water layer, and the development is not put into practice all the time.
The following calculations were performed using the preferred embodiment of the present invention:
using sonic logging data to obtain phie＝0.096，φa＝0.144，Vsh＝0.246。
Formula phi derived according to the inventionm＝1-Vsh-φa，φo＝(1-Sw)φa，φwl＝φe-(1-Sw)φa；φws＝φa-φeObtaining:
φws＝φa-φe＝0.048；
φwl＝0.144Sw-0.048；
φo＝0.144(1-Sw)；
φm＝1-Vsh-φa＝0.61。
substituting the above parameters into formula (12)
By using a rapid simulated annealing method, SwAt (0.33, 1)]Optimizing within a range to satisfy an objective function
The calculated water saturation was 26.5% and the oil saturation was 73.5%, which was reinterpreted as the reservoir.
The fracturing test oil day of the reservoirOil production of 40.75m3Daily fracturing fluid 3.9m3And the method is consistent with the calculation result, so that the method has a better application effect.
It should be understood that the above-mentioned embodiments of the present invention are only examples for clearly illustrating the present invention, and are not intended to limit the embodiments of the present invention, and it will be obvious to those skilled in the art that other variations or modifications may be made on the basis of the above description, and all embodiments may not be exhaustive, and all obvious variations or modifications may be included within the scope of the present invention.
Claims (10)
1. A method for calculating the water saturation of a hypotonic reservoir is characterized by comprising the following steps of:
s100, obtaining the resistivity of argillaceous and formation water, parameters reflecting the structure and connectivity of a rock reservoir, the conductivity of saturated rock, the connected porosity, the total porosity and the argillaceous content; counting the ratio of the movable formation water volume to the immobile formation water volume in the reservoir;
and S200, calculating the water saturation of the reservoir according to the obtained parameters.
2. The method for calculating the water saturation of a hypotonic reservoir according to claim 1, wherein S100 specifically comprises:
obtaining the resistivity of the argillaceous and formation water and parameters reflecting the structure and connectivity of a rock reservoir according to a laboratory core physical experiment;
according to the observation of the core slice, the ratio of the volume of movable formation water to the volume of immobile formation water in the reservoir is counted;
obtaining the conductivity of the saturated rock according to the resistivity of the saturated rock in the logging data;
obtaining the connected porosity by using acoustic logging data;
obtaining total porosity using density log data;
and obtaining the shale content by utilizing natural gamma logging data.
3. The method of calculating water saturation of a hypotonic reservoir of claim 1, wherein the parameters reflecting rock reservoir structure and connectivity include λsh、λwl、γsh、γwl、γo；
Lambda and gamma are component characteristic parameters, lambda reflects the connectivity of the component, and gamma reflects the shape and structure of the component; subscripts sh, o, wl denote shale, oil, mobile formation water, respectively.
4. The method for calculating the water saturation of a hypotonic reservoir according to claim 3, wherein in S200, the water saturation S is calculated by using a rapid simulated annealing methodwSubstituted into the model in the interval [0,1]]Carrying out iterative solution to calculate the water saturation of the reservoir;
the model is as follows:
φm+Vsh+φaas 1 type (8)
φa＝φo+φw＝φo+φwl+φwsFormula (9)
Wherein C is the conductivity, CtConductivity of saturated rock in units of S/m;
phi is the volume fraction of each component, and the value range is (0, 1); phi is aeIs connected with the porosity of the pores and has a value of phie＝φo+φwl；φaIs the total porosity;
n is the ratio of the movable formation water volume to the immobile formation water volume in the reservoir;
lambda and gamma are component characteristic parameters, and the value ranges are [0,1 ]; λ reflects the connectivity of the component, γ reflects the shape and structure of the component;
Vshthe values are all [0,1] for the argillaceous content]；
Subscripts sh, o, wl, ws, m, w represent argillaceous, oil, mobile formation water, immobile formation water in the microporosity, matrix framework, and formation water, respectively.
5. The method of calculating water saturation of a hypotonic reservoir of claim 4, wherein the saturation rock conductivity is calculated by equation (16):
wherein R istThe resistivity of the saturated rock is in units of omega meters; ctIs the conductivity of saturated rock in units of S/m.
6. The method of calculating water saturation of a hypotonic reservoir of claim 5, wherein the method is based on a resulting interconnected porosity φeTotal porosity phiaMud content VshPhi is obtained by the following formulam、φo、φwl、φws：
φm＝1-Vsh-φa，φo＝(1-Sw)φa，φwl＝φe-(1-Sw)φa，φws＝φa-φe；
And directly substituting the water saturation into the formula (12) to obtain the water saturation SwIn the formula (12), in the interval [0,1]]And carrying out iterative solution to calculate the water saturation of the reservoir.
7. The method of calculating the water saturation of a hypotonic reservoir of claim 1, comprising the steps of:
s100, obtaining the resistivity C of the muddy and formation water according to the physical experiment of the laboratory rock coresh、CwlAnd a parameter λ reflecting the rock reservoir structure and connectivitysh、λwl、γsh、γwl、γo；
According to the observation of the core slice, counting the volume ratio n of movable formation water to immobile formation water in the reservoir;
from the saturated rock resistivity R in the log datatObtaining the conductivity C of the saturated rockt；
Obtaining connected porosity phi from sonic logging dataeAnd has a diameter ofe＝φo+φwl；
Obtaining total porosity phi from density log dataa；
Obtaining the mud content V by using natural gamma well logging datash；
S200, utilizing a rapid simulated annealing method and utilizing the rapid simulated annealing method to obtain the water saturation SwSubstituted into the model in the interval [0,1]]Carrying out iterative solution to calculate the water saturation of the reservoir;
the model is as follows:
φm+Vsh+φaas 1 type (8)
φa＝φo+φw＝φo+φwl+φwsFormula (9)
Wherein C is the conductivity, CtConductivity of saturated rock in units of S/m;
phi is the volume fraction of each component, and the value ranges are (0, 1); phi is aeIs connected with the porosity of the pores and has a value of phie＝φo+φwl；φaIs the total porosity;
n is the ratio of the movable formation water volume to the immobile formation water volume in the reservoir;
lambda and gamma are component characteristic parameters, and the value ranges are [0,1 ]; λ reflects the connectivity of the component, γ reflects the shape and structure of the component;
Vshthe values are all [0,1] for the argillaceous content]；
Subscripts sh, o, wl, ws, m, w represent argillaceous, oil, mobile formation water, immobile formation water in the microporosity, matrix framework, and formation water, respectively.
8. The method of calculating water saturation of a hypotonic reservoir of claim 7, wherein the method is based on a resulting interconnected porosity φeTotal porosity phiaMud content VshPhi is obtained by the following formulam、φo、φwl、φws：
φm＝1-Vsh-φa，φo＝(1-Sw)φa，φwl＝φe-(1-Sw)φa，φws＝φa-φe；
And directly substituting the water saturation into the formula (12) to obtain the water saturation SwIn the formula (12), in the interval [0,1]]And carrying out iterative solution to calculate the water saturation of the reservoir.
9. The method for calculating the water saturation of a hypotonic reservoir according to any one of claims 4-8, characterized by letting SwAt (0.33, 1)]Optimizing within the range.
10. The method for calculating the water saturation of a hypotonic reservoir according to any one of claims 4-8, wherein an objective function is satisfied during iterative solution
I.e. stopping iteration to obtain the optimal solution.
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| CN101135732A (en) * | 2006-08-31 | 2008-03-05 | 中国石油大学(北京) | Formation fluid saturation degree evaluating method |
| CN103422853A (en) * | 2012-05-24 | 2013-12-04 | 中国石油天然气集团公司 | Method and device for determining water saturation of stratum |
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| CN101135732A (en) * | 2006-08-31 | 2008-03-05 | 中国石油大学(北京) | Formation fluid saturation degree evaluating method |
| CN103422853A (en) * | 2012-05-24 | 2013-12-04 | 中国石油天然气集团公司 | Method and device for determining water saturation of stratum |
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