CN113719277B - Hypotonic reservoir water saturation calculation method - Google Patents
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 71
- 238000004364 calculation method Methods 0.000 title claims abstract description 27
- 239000011435 rock Substances 0.000 claims abstract description 47
- 239000008398 formation water Substances 0.000 claims abstract description 32
- 229920006395 saturated elastomer Polymers 0.000 claims abstract description 31
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- 239000011148 porous material Substances 0.000 claims description 11
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- 230000035699 permeability Effects 0.000 description 4
- 238000004519 manufacturing process Methods 0.000 description 3
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Abstract
The invention discloses a hypotonic reservoir water saturation calculation method, which comprises the following steps of: obtaining the shale and formation water resistivity, parameters reflecting the structure and connectivity of the rock reservoir, saturated rock conductivity, connected porosity, total porosity and shale content; and counting the ratio of the volume of movable stratum water to the volume of the stationary stratum water in the reservoir; the water saturation of the reservoir is calculated from the resulting parameters. The method starts from an effective medium conduction theory, establishes a saturated rock model of the hypotonic reservoir, deduces the relation between the resistivity of the saturated rock and the water saturation, and effectively improves the prediction precision of the water saturation of the hypotonic reservoir. The invention can be applied to the identification of oil and water layers of a hypotonic reservoir, and has important significance for optimizing the perforation well section, effectively avoiding water and improving the development effect.
Description
Technical Field
The invention relates to the field of petroleum logging engineering, in particular to a method for calculating water saturation of a hypotonic reservoir.
Background
Typically, fluid saturation may be expressed by the Archie's empirical formula, but the Alqi formula applies under conditions of pure sandstone simple pores. As oilfield exploration and development continue to advance, the goals of oilfield exploration and development have shifted toward low-grade reservoirs. The low-grade oil reservoir has the characteristics of low porosity, low permeability, compact reservoir and the like, and the conductivity of the reservoir rock is greatly different from that of the conventional reservoir resistance under the complex geological conditions, so that the non-Alqi relationship is obvious. The oil layer is difficult to accurately identify, so that the dynamic and static data are not matched, the geological knowledge is unclear, and great difficulty is caused to the increase of the storage and the production of the oil reservoir.
Disclosure of Invention
The invention aims to provide a method for calculating the water saturation of a hypotonic reservoir, which can effectively improve the calculation accuracy compared with an Archie formula.
In order to achieve the above purpose, the present invention adopts the following technical scheme:
the invention provides a hypotonic reservoir water saturation calculation method, which comprises the following steps of:
s100, obtaining the shale and formation water resistivity, parameters reflecting the structure and connectivity of a rock reservoir, saturated rock conductivity, communication porosity, total porosity and shale content; and counting the ratio of the volume of movable stratum water to the volume of the stationary stratum water in the reservoir;
and S200, calculating the water saturation of the reservoir according to the obtained parameters.
According to the hypotonic reservoir water saturation calculation method of the present invention, preferably, S100 specifically includes:
obtaining the clay and stratum water resistivity according to a laboratory core physical experiment, and reflecting parameters of the rock reservoir structure and connectivity;
according to the core slice observation, calculating the ratio of the volume of movable stratum water to the volume of immovable stratum water in the reservoir;
obtaining saturated rock conductivity according to the saturated rock resistivity in the logging data;
obtaining the porosity of the communicated porosity by using acoustic logging information;
obtaining a total porosity using the density log data;
and obtaining the clay content by using natural gamma logging data.
According to the hypotonic reservoir water saturation calculation method of the present invention, preferably, the parameter reflecting the rock reservoir structure and connectivity comprises λ sh 、γ wl 、γ sh 、γ wl 、γ o ；
Lambda and gamma are characteristic parameters of the component, lambda reflects connectivity of the component, and gamma reflects the shape and structure of the component; subscripts sh, o, wl represent argillaceous, oil, mobile formation water, respectively.
According to the hypotonic reservoir water saturation calculation method of the present invention, preferably, in S200, the water saturation S is calculated by a rapid simulated annealing method w In the model, in interval [0,1]]Performing iterative solution to calculate the water saturation of the reservoirDegree of sum; when S is w When=1, the water content is 100%, pure water is in the pores, and the water layer is the water layer; s is S w When=0 (theoretically), the water content is 0, the pores are pure oil, and the pores are pure oil layers. Normally the subsurface reservoir contains water, while the water layer may be devoid of oil, so Sw is often (0, 1]。
The model is as follows:
φ m +V sh +φ a =1 (8)
φ a ＝φ o +φ w ＝φ o +φ wl +φ ws (9)
Wherein C is conductivity, C t Is the conductivity of saturated rock, and the unit is S/m;
phi is the volume fraction of each component, and the value range is (0, 1); phi (phi) e To communicate porosity and have phi e ＝φ o +φ wl ；φ a Is the total porosity;
n is the ratio of the volume of movable formation water to the volume of stationary formation water in the reservoir;
lambda and gamma are component characteristic parameters, and the value ranges are 0, 1; λ reflects the connectivity of the component, and γ reflects the shape and structure of the component;
V sh the value ranges of the clay content are 0,1]；
Subscripts sh, o, wl, ws, m, w represent the shale, oil, mobile formation water, stationary formation water in the microporosity, matrix backbone, and formation water, respectively.
According to the hypotonic reservoir water saturation calculation method of the present invention, preferably, the saturated rock conductivity is calculated by formula (16):
wherein R is t The resistivity of the saturated rock is expressed in omega-meters; c (C) t Is the saturated rock conductivity in S/m.
The hypotonic reservoir water saturation calculation method according to the invention preferably is based on the resulting interconnected porosity phi e Total porosity phi a Content of argillaceous V sh Phi is obtained by the following formula m 、φ o 、φ wl 、φ ws ：
φ m ＝1-V sh -φ a ，φ o ＝(1-S w )φ a ，φ wl ＝φ e -(1-S w )φ a ，φ ws ＝φ a -φ e ；
And substituting it directly into (12) to obtain the water saturation S w Substituted into (12) in the interval [0,1]]And (5) performing iterative solution, and calculating the water saturation of the reservoir.
According to the hypotonic reservoir water saturation calculation method of the present invention, preferably, the hypotonic reservoir water saturation calculation method comprises the steps of:
s100, obtaining the muddy and formation water resistivity C according to a laboratory core physical experiment sh 、C wl And a parameter lambda reflecting rock reservoir structure and connectivity sh 、λ wl 、γ sh 、γ wl 、γ o ；
According to the observation of the rock core sheet, counting the ratio n of the volume of movable stratum water to the volume of immovable stratum water in the reservoir;
from saturated rock resistivity R in log data t Obtaining the saturated rock conductivity C t ；
Obtaining a connected porosity phi using sonic logging data e And has phi e ＝φ o +φ wl ；
Obtaining total porosity phi using densitometric data a ；
Obtaining the shale content V by using natural gamma logging data sh ；
S200, substituting the water saturation Sw into a model by using a rapid simulated annealing method, carrying out iterative solution between intervals [0,1] and calculating the water saturation of the reservoir;
the model is as follows:
φ m +V sh +φ a =1 (8)
φ a ＝φ o +φ w ＝φ o +φ wl +φ ws (9)
Wherein C is conductivity, C t Is the conductivity of saturated rock, and the unit is S/m;
phi is the volume fraction of each component, and the value range is (0, 1); phi (phi) e To communicate porosity and have phi e ＝φ o +φ wl ；φ a Is the total porosity;
n is the ratio of the volume of movable formation water to the volume of stationary formation water in the reservoir;
lambda and gamma are component characteristic parameters, and the value ranges are 0, 1; λ reflects the connectivity of the component, and γ reflects the shape and structure of the component;
V sh the value ranges of the clay content are 0,1]；
Subscripts sh, o, wl, ws, m, w represent the shale, oil, mobile formation water, stationary formation water in the microporosity, matrix backbone, and formation water, respectively.
The hypotonic reservoir water saturation calculation method according to the invention preferably is based on the resulting interconnected porosity phi e Total porosity phi a Content of argillaceous V sh Phi is obtained by the following formula m 、φ o 、φ wl 、φ ws ：
φ m ＝1-V sh -φ a ，φ o ＝(1-S w )φ a ，φ wl ＝φ e -(1-S w )φ a ，φ ws ＝φ a -φ e ；
And substituting it directly into (12) to obtain the water saturation S w Substituted into (12) in the interval [0,1]]And (5) performing iterative solution, and calculating the water saturation of the reservoir.
The hypotonic reservoir water saturation calculation method according to the invention preferably lets S w At (0.33,1)]And optimizing in the range. The unit volume of a rock is 1 phi a +V sh +φ m =1, any value inside only>0 is physically significant, thus in the example application, phi wl ＝0.144S w -0.048>0, get S w Greater than 0.33.
The hypotonic reservoir water saturation calculation method according to the invention preferably satisfies the objective function when solving iterativelyAnd stopping iteration to obtain the optimal solution. More preferably, the->The iteration is stopped, the convergence accuracy is good, and the calculation time is short.
In the practical application process, rock physical experiments are utilized to determine the structure and connectivity parameters of the rock, and the water saturation of the reservoir is calculated by utilizing the proposed novel calculation model. Compared with an Aldrich formula, the calculation accuracy is effectively improved.
Specifically, the calculation model derivation process of the invention is specifically as follows:
according to the effective medium symmetrical conduction theory, the conductivity of saturated rock has the following formula (1):
wherein N is the component number contained in the saturated rock; c is conductivity, unit S/m is the reciprocal of resistivity; subscripts sat, i represent saturated rock and the ith component, respectively; phi (phi) i Is the volume fraction of the i-th component; c (C) og The expression of (2) is:
lambda and gamma are characteristic parameters of the component, lambda reflects connectivity of the component, and gamma reflects the shape and structure of the component.
For aqueous pure sandstone, the saturated rock is composed of a sandstone matrix skeleton and aqueous pores, and the conductivity has the following formulas (3) and (4):
wherein, subscripts m and w respectively represent a matrix skeleton and formation water.
Since the rock is composed of only aqueous pores and sandstone matrix skeleton, there is formula (5):
φ m +φ w =1 (5)
The sandstone matrix skeleton is not conductive, and therefore C m =0; at the same time for homogeneous rock there is gamma m ＝γ w . Then there are formula (6) and formula (7):
the shale and microporosity in the hypotonic reservoir develop relatively, and the complex pore structure characteristics and fluid properties affect the conductivity of saturated rock. Unlike sandstone matrix skeleton, the surface of mudstone particle is easy to adsorb ionic mineral and has certain conductivity. Meanwhile, under the influence of dispersed clay in a reservoir, the communication performance among the micropores is poor, the fluid fluidity is low, no effective migration channel is formed in the oil and gas migration process, and formation water in the micropores is not displaced. From this, formula (8) and formula (9) can be derived:
φ m +V sh +φ a =1 (8)
φ a ＝φ o +φ w ＝φ o +φ wl +φ ws (9)
Wherein V is sh For saturated rock shale content, subscripts a, o, w l 、w s Representing total pore, oil, mobile formation water, and stationary formation water in micropores, respectively.
Substituting formula (8) and formula (9) into formula (1) to obtain formula (10):
c taking into account the conductivity of the components m ＝C o =0; since the micropores are not connected, C ws =0; obtaining the formula (11):
the formula (11) is finished to obtain a formula (12):
meanwhile, the communication pores distributed in the matrix skeleton are filled with oil and movable stratum water to obtain gamma o ＝γ wl ，λ m ≈λ o ＝λ wl The method comprises the steps of carrying out a first treatment on the surface of the Substituted into formula (2), formula (13) is given:
the low permeability reservoir production needs to be subjected to fracturing transformation, and the fracturing technology enables micropores to be communicated, so that the seepage capability of fluid is improved; thus for hypotonic reservoirs the water saturation S w Is of formula (14):
assuming a ratio n of mobile formation water to stationary formation water volume in the reservoir; then formula (14) is formula (15):
by resistivity logging, the saturated rock resistivity is R t Saturated rock conductivity C t Is of formula (16):
therefore, the calculation model obtained by the invention is as follows:
φ m +V sh +φ a =1 (8)
φ a ＝φ o +φ w ＝φ o +φ wl +φ ws (9)
Wherein C is conductivity, C t Is the conductivity of saturated rock, and the unit is S/m;
phi is the volume fraction of each component; phi (phi) e To communicate porosity and have phi e ＝φ o +φ wl ；φ a Is the total porosity;
n is the ratio of the volume of movable formation water to the volume of stationary formation water in the reservoir;
lambda and gamma are characteristic parameters of the component, lambda reflects connectivity of the component, and gamma reflects the shape and structure of the component;
V sh is the clay content;
subscripts sh, o, wl, ws, m, w represent the shale, oil, mobile formation water, stationary formation water in the microporosity, matrix backbone, and formation water, respectively.
The () or [ ] symbols in the range of values referred to in the present invention are not essentially different, since the values are not normally limited to two sides at the time of actual calculation.
The method can directly calculate the water saturation of the reservoir according to the petrophysical experiment, various logging data and the like by using the model; compared with an Aldrich formula, the calculation accuracy is effectively improved.
The method starts from an effective medium conduction theory, establishes a saturated rock model of the hypotonic reservoir, deduces the relation between the resistivity of the saturated rock and the water saturation, and effectively improves the prediction precision of the water saturation of the hypotonic reservoir. The invention can be applied to the identification of oil and water layers of a hypotonic reservoir, and has important significance for optimizing the perforation well section, effectively avoiding water and improving the development effect.
Drawings
FIG. 1 is a graph of well log data and reinterpretation results for a well according to an embodiment of the present invention.
Detailed Description
In order to more clearly illustrate the present invention, the present invention will be further described with reference to preferred embodiments. It is to be understood by persons skilled in the art that the following detailed description is illustrative and not restrictive, and that this invention is not limited to the details given herein.
The present invention provides a specific application example herein, and the storage conditions involved are as follows:
the oil-gas-containing layer is a sand section, the oil reservoir burial depth is 3100-4020 m, the average porosity of the reservoir is 12.1%, the permeability is 1.48mD, and the oil-gas-containing layer is a low-pore low-ultra-low permeability reservoir. According to the rock core experimental data of the exploratory well, lambda is determined sh ＝0.82，λ wl ＝0.27，γ sh ＝0.75，γ wl ＝0.22，γ o ＝0.18。
As shown in FIG. 1, in the well section 3549.8-3554.3 of the hollow A well, the acoustic time difference is 77.2ms/m and the density is 2.41g/cm in the layer 36 3 The deep lateral resistivity is 11.2 Ω·m, the natural gamma is 61.1API, the water saturation is 99.4% calculated by using the alchi formula, which is interpreted as the same layer of oil and water, and has not been developed in the past.
The following calculations were performed using the preferred embodiment of the present invention:
obtaining phi by using acoustic logging data e ＝0.096，φ a ＝0.144，V sh ＝0.246。
The formula phi derived according to the invention m ＝1-V sh -φ a ，φ o ＝(1-S w )φ a ，φ wl ＝φ e -(1-S w )φ a ；φ ws ＝φ a -φ e The method comprises the following steps:
φ ws ＝φ a -φ e ＝0.048；
φ wl ＝0.144S w -0.048；
φ o ＝0.144(1-S w )；
φ m ＝1-V sh -φ a ＝0.61。
substituting the above parameters into the formula (12)
S is made by using a rapid simulated annealing method w At (0.33,1)]Optimizing in the range to meet the objective function The calculated water saturation was 26.5% and the oil saturation was 73.5% and was re-interpreted as the oil layer.
The reservoir fracturing test oil daily oil production is 40.75m 3 Daily-produced fracturing fluid 3.9m 3 And the method accords with the calculation result, which shows that the method has a better application effect.
It should be understood that the foregoing examples of the present invention are provided merely for clearly illustrating the present invention and are not intended to limit the embodiments of the present invention, and that various other changes and modifications may be made therein by one skilled in the art without departing from the spirit and scope of the present invention as defined by the appended claims.
Claims (6)
1. A method for calculating the water saturation of a hypotonic reservoir, the method comprising the steps of:
s100, obtaining the shale and formation water resistivity, parameters reflecting the structure and connectivity of a rock reservoir, saturated rock conductivity, communication porosity, total porosity and shale content; and counting the ratio of the volume of movable stratum water to the volume of the stationary stratum water in the reservoir;
s200, calculating the water saturation of the reservoir according to the obtained parameters;
the parameters reflecting rock reservoir structure and connectivity include lambda sh 、λ wl 、γ sh 、γ wl 、γ o ；
Lambda and gamma are characteristic parameters of the component, lambda reflects connectivity of the component, and gamma reflects the shape and structure of the component; subscripts sh, o, wl represent argillaceous, oil, mobile formation water, respectively;
in S200, the water saturation S is calculated by using a rapid simulated annealing method w In the model, in interval [0,1]]Performing iterative solution, and calculating the water saturation of the reservoir;
the model is as follows:
φ m +V sh +φ a =1 (8)
φ a ＝φ o +φ w ＝φ o +φ wl +φ ws (9)
Wherein C is conductivity, C t Is the conductivity of saturated rock, and the unit is S/m;
phi is the volume fraction of each component, and the value range is (0, 1); phi (phi) e To communicate porosity and have phi e ＝φ o +φ wl ；φ a Is the total porosity;
n is the ratio of the volume of movable formation water to the volume of stationary formation water in the reservoir;
lambda and gamma are component characteristic parameters, and the value ranges are 0, 1; λ reflects the connectivity of the component, and γ reflects the shape and structure of the component;
V sh the value ranges of the clay content are 0,1]；
Subscripts sh, o, wl, ws, m, w represent the shale, oil, mobile formation water, stationary formation water in the microporosity, matrix backbone, and formation water, respectively.
2. The method of hypotonic reservoir water saturation calculation according to claim 1, wherein S100 comprises in particular:
obtaining the clay and stratum water resistivity according to a laboratory core physical experiment, and reflecting parameters of the rock reservoir structure and connectivity;
according to the core slice observation, calculating the ratio of the volume of movable stratum water to the volume of immovable stratum water in the reservoir;
obtaining saturated rock conductivity according to the saturated rock resistivity in the logging data;
obtaining the porosity of the communicated porosity by using acoustic logging information;
obtaining a total porosity using the density log data;
and obtaining the clay content by using natural gamma logging data.
3. The hypotonic reservoir water saturation calculation method of claim 1, wherein the saturated rock conductivity is calculated by equation (16):
wherein R is t The resistivity of the saturated rock is expressed in omega-meters; c (C) t Is the saturated rock conductivity in S/m.
4. A hypotonic reservoir aqueous according to claim 3A saturation calculation method is characterized by comprising the step of calculating the porosity phi of the connected pores according to the obtained method e Total porosity phi a Content of argillaceous V sh Phi is obtained by the following formula m 、φ o 、φ wl 、φ ws ：
φ m ＝1-V sh -φ a ，φ o ＝(1-S w )φ a ，φ wl ＝φ e -(1-S w )φ a ，φ ws ＝φ a -φ e ；
And substituting it directly into (12) to obtain the water saturation S w Substituted into (12) in the interval [0,1]]And (5) performing iterative solution, and calculating the water saturation of the reservoir.
5. The method for calculating the water saturation of a hypotonic reservoir according to any one of claims 1 to 4, wherein the method comprises the steps of w At (0.33,1)]And optimizing in the range.
6. The method of claim 4, wherein the objective function is satisfied when iteratively solvingAnd 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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