CN108229051A - A kind of method of oil reservoir prediction air foam flooding shaft recovery ratio - Google Patents
A kind of method of oil reservoir prediction air foam flooding shaft recovery ratio Download PDFInfo
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- 239000006260 foam Substances 0.000 title claims abstract description 190
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Abstract
The invention belongs to oil field development technical field, more particularly to a kind of computational methods of oil reservoir prediction air foam flooding shaft recovery ratio.A kind of method of oil reservoir prediction air foam flooding shaft recovery ratio, includes the following steps：（1）Assuming that injection fluid can gradually form three regions, i.e. froth zone, liquid phase region and gas phase zone, and the displacement stage is divided into before breakthrough of gas and after breakthrough of gas in stratum, judge that the current generation belongs to a certain stage in displacement stage；（2）Current generation to be determined is before breakthrough of gas or after breakthrough of gas, calculates the displacement efficiency and sweep efficiency of froth zone, each region in liquid phase region and gas phase zone under the current generation respectively.（3）Recovery ratio R=displacement efficiency × sweep efficiency.Displacement fluid in oil reservoir is divided into three regions by the present invention, and then the sweep efficiency to each region and oil displacement efficiency calculate respectively, finally obtains the recovery ratio of air foam flooding shaft, and feasibility and operability are strong.
Description
Technical Field
The invention belongs to the technical field of oilfield development, and particularly relates to a calculation method for predicting the recovery ratio of air foam flooding of an oil reservoir.
Background
The oil reservoir recovery rate is an important evaluation index in oil field development. The recovery effect of the oil reservoir under different driving modes can be evaluated and the recoverable reserves can be calculated through recovery prediction, and the method has important significance for oil field development planning and scheme deployment. According to the experience of a large amount of oil reservoir development at home and abroad, the factors influencing the oil reservoir recovery ratio are various, and besides the factors such as oil reservoir characteristics, natural energy, stratum fluid properties, well pattern types and the like, the factors are closely related to the development mode and the driving type.
Air foam flooding is an effective technical method for improving the recovery ratio of oil reservoirs, and has good application effects in many oil field developments at home and abroad at present. The investigation proves that the conventional method for predicting the recovery ratio of the air foam flooding mainly comprises a physical experiment method and a numerical simulation method, and a perfect and effective theoretical calculation method is lacked. The physical experiment method carries out an indoor core displacement experiment by simulating an oil reservoir and fluid conditions, calculates the predicted recovery ratio according to experimental data, has long time consumption and high required cost, and generally obtains only one-dimensional displacement recovery ratio, namely displacement efficiency, by the indoor physical experiment, and has larger recovery ratio difference with the actual oil reservoir displacement under the condition of sweep efficiency. The numerical simulation method firstly needs to establish a precise and accurate oil reservoir geological model and carries out the prediction of the recovery ratio on the basis of carrying out good fitting with the production historical data, needs a large amount of detailed and effective data information, has large workload of early preparation and later calculation and processing, and also has long time consumption.
Disclosure of Invention
The invention aims to solve the problems and provides a method for quantitatively calculating the recovery ratio by stages before and after gas breakthrough in a displacement stage.
The technical scheme of the invention is as follows:
a method for predicting the recovery ratio of air foam flooding of an oil reservoir comprises the following steps:
(1) assuming that the injected fluid can gradually form three areas, namely a foam area, a liquid phase area and a gas phase area, and dividing the displacement stage into a certain stage of the displacement stage before gas breakthrough and a certain stage after gas breakthrough;
(2) respectively calculating the displacement efficiency and the sweep efficiency of each area of the foam area, the liquid phase area and the gas phase area in the current stage before or after the current stage is determined to be gas breakthrough;
(3) recovery ratio R = displacement efficiency × sweep efficiency.
When in useA btfoam +A btwater +A btgas< A total When the sum of the swept areas of the three regions is smaller than the whole oil reservoir area, the gas is considered to be not broken through; when in useA btfoam +A btwater +A btgas= A total When the sum of the swept areas of the three regions occupies the whole oil reservoir, the gas is considered to break through at the moment; when in useA btfoam +A btwater= A total When the sum of the swept areas of the water-based liquid phase region and the foam region occupies the whole oil reservoir, the gas phase region is considered to be completely broken through; according to definition and seepage mechanics, the area of each region can be calculated by the following formula:
（1）
（2）
（3）
wherein, ①CIs a well pattern related coefficient; when a five-point well pattern is used,C= 0.718; when an inverted seven-point pattern is used,C= 0.743; when an inverse nine-point pattern is used,C=0.525；
②、andrespectively, the pseudo-fluidity ratio of the foam and the crude oil, the pseudo-fluidity ratio of the foam liquid and the crude oil, and the pseudo-fluidity ratio of the gas and the crude oil, which are respectively determined byCorresponding to the fluidity ratio of the two fluids under the homogeneous conditionMAnd coefficient of permeability variationVAccording to the fitting relation of the wave and coefficients of the fluids with different fluidity ratios under the heterogeneous condition, the fitting relation is respectively calculated by the following formulas:
when in useV≤0.7When the temperature of the water is higher than the set temperature,
（4）
when in useV＞0.7When the temperature of the water is higher than the set temperature,
(5)
③ calculationA foam : firstly, calculating the residual foam amount by using the data of the foam half-life:
（6）
wherein,V left for a certain complete slug transit timetThe remaining volume of foam;V i the volume of a foam slug as it is formed is assumed in the calculation to be the sum of the volume of injected air and foaming system solution at formation pressure, thus the total injected volume of fluid for each slug;Tis the foam half-life;
swept volume of the foam zoneV foam The following can be calculated:
（7）
wherein,S wc irreducible water saturation;S orfoam residual oil saturation for foam flooding equal to the relative permeability of the foam to the crude oilThe endpoint value when the relative permeability of crude oil in the rate curve is 0;
the swept area of the foam zone is as follows:
（8）
the swept area of the water-based liquid phase region, which is generated by the collapse of the foam, can be calculated from its physical significance by the following formula:
（9）
wherein,φin order to determine the porosity of the reservoir,hthe thickness of the oil reservoir is taken as the oil reservoir thickness,λ water representing the volume ratio of the foaming system solution in each injection slug,S orwater the residual oil saturation of the foam liquid flooding is equal to the endpoint value when the relative permeability of the foam liquid and the crude oil in the relative permeability curve of the crude oil is 0;
the swept area of the gas phase region comes from the air which can not form foam after the fluid is injected and the swept area formed by the gas generated after the foam is broken at the front edge part, and can be expressed as follows according to the physical meaning:
（10）
wherein,λ gas representing the volume ratio occupied by the gas in each injection slug,S orgas residual oil saturation for gas flooding, which is equal to the endpoint value when the relative permeability of the gas to crude oil in the relative permeability curve of the gas to crude oil is 0,Rindicating the reaction coefficient of the gas, known from low-temperature oxidationR=0.996。
The calculation of the recovery ratio before breakthrough comprises three parts, namely the recovery ratio of a foam zone, the recovery ratio of a liquid zone and the recovery ratio of a gas zone;
wherein the foam area recovery ratio calculation process is as follows:
① calculating sweep coefficients
Ev foam = Ez foam ×Es foam （11）
Wherein,Es foam is the plane sweep coefficient of the foam area,Ez foamm longitudinal sweep efficiency of the foam zone
（12）
（13）
Wherein,Mis the ratio of the fluidity of the foam to the crude oil,is the ratio of viscous force to gravity
（14）
In the formula,μ t the permeation speed of the foam is shown,μ 0 in order to be the viscosity of the crude oil in the formation,χthe distance of the oil reservoir along the direction of water injection,K x for transverse permeability, Δ ρ is the density difference of the displacement fluid and the displaced fluid;
② calculating Displacement efficiency
（15）
In the formula,S oi is the original oil saturation;
③ calculated recovery ratio:
RF foam =Ed foam ×Ev foam （16）；
similarly, the liquid phase region recovery process is as follows:
Ev water =Ez water ×Es water （17）
wherein,Es water is the planar sweep coefficient of the foam liquid,Ez water the longitudinal sweep coefficient of the foam liquid is shown;Ez water the fluidity ratio of the foaming system solution and the crude oil is substituted into the formula (13) for calculation;
（18）
（19）
liquid phase zone recoveryRF water Comprises the following steps:
RF water = Ed water ×Ev water （20）
similarly, the gas phase zone recovery process is as follows:
Ev gas =Ez gas ×Es gas （21）
wherein,Es gas is a planar sweep coefficient of the gas,Ez gas is the longitudinal sweep coefficient of the gas;Ez gas substitution from gas to crude oil fluidity ratioCalculating the formula (13);
（22）
（23）
recovery of gas phase zoneRF gas Comprises the following steps:
RF gas = Ed gas ×Ev gas （24）
the total recovery ratio before gas breakthrough is as follows:
RF= RF foam ＋RF water ＋RF gas 。
the recovery ratio after breakthrough comprises three parts, namely foam zone recovery ratio, liquid zone recovery ratio and gas zone recovery ratio;
(1) calculating the volume sweep coefficient:
plane sweep coefficient in breakthrough for homogeneous reservoirEs bt The following formula:
（25）
broken plane sweep coefficientEs afterbt The following formula:
（26）
wherein,Dfor coefficients relating to the pattern type, when a five-point pattern is used,D=0.2749(ii) a When using a reverse seven-point well patternWhen the temperature of the water is higher than the set temperature,D =0.2351(ii) a When an inverse nine-point pattern is used,D=0.201；V ibt volume of injected fluid for breakthrough;
plane sweep coefficient in breakthrough for heterogeneous reservoirEs bt The following formula:
（27）
broken plane sweep coefficientEs afterbt The following formula:
（28）
wherein the coefficientsUsed for limiting the planar sweep coefficient after breakthrough to lead the planar sweep coefficient to tend to the maximum planar sweep coefficient under the conditions of the current fluidity ratio and the permeability coefficient of variationEs max The calculation method is as follows:
（29）
longitudinal sweep coefficient after breakthroughEz afterbt The calculation method is the same as the formula (13);
volume sweep coefficient
Ev afterbt =Ez afterbt ×Es afterbt （33）；
(2) Calculating dynamic oil displacement efficiencyE d Comprises the following steps:
（34）
wherein,S d in order to displace the fluid dynamic saturation,for residual oil saturation at dynamic displacement,；
according to the theory of water saturation of the front edge of the seepage mechanics, the volume multiple of the injected pores is accumulatedPVIs the inverse of the rate of change of water content to water saturation, i.e.
（35）
Meanwhile, according to the theory of seepage mechanics, the water contentf w Can be expressed as:
（36）
according to the relative permeability of two phases of oil and foam liquidK ro AndK rw is a function of the water saturation, which in turn can be generally expressed as:
（37）
whereina、bAs a coefficient, can be obtained byAndsemi-logarithmic seatLinear regression of the plot;
substituting formula (37) for formula (36) and deriving to obtain
（38）
（39）
The cumulative injection pore volume multiple may be determined from the cumulative amount of injection fluid, i.e.:
（40）
whereinB w Is the volume factor of the formation water,Athe area of the oil-containing layer is,hthe thickness of the oil reservoir is taken as the oil reservoir thickness,φin order to determine the porosity of the reservoir,ρ w is the density of the foam liquid;
the given value can be obtained by using the above formulaPVThe corresponding water content at the moment can be obtained according to the fluidity ratio of the number; then according to the seepage mechanics water phase flow-dividing formula, the dynamic average water saturation at the moment can be obtainedI.e. dynamic saturation of the displacement fluidS d Namely:
（41）
wherein,μ w the viscosity of the foam concentrate is used as the viscosity of the foam concentrate,μ 0 is the formation crude oil viscosity;
the oil displacement efficiency is substituted into a formula (34) of the oil displacement efficiency, and the dynamic average oil displacement efficiency of the oil deposit at the moment can be obtained:
（42）
(3) calculated recovery ratio
Obtaining the recovery ratio according to the calculated volume sweep coefficient and the oil displacement efficiencyRFThe calculation is as follows:
RF=Ed×Ev（43）。
saidEs max The calculation method of (2) is as follows:
value at the cut-off point when the permeability coefficient of variation changes from low to high is introducedV c The relationship between the fluidity ratio and the fluidity ratio can be calculated by the following formula:
（30）
coefficient of permeability variationV＜V c When the maximum plane sweep efficiency is as follows,
（31）
coefficient of permeability variationV≥V c The maximum plane sweep coefficient is
（32）。
The invention has the technical effects that:
according to the air foam flooding mechanism, the displacement fluid in the oil reservoir is divided into three areas, and then the sweep efficiency and the flooding efficiency of each area are respectively calculated, so that the recovery ratio of the air foam flooding is finally obtained. The related parameters in the calculation formula are easy to obtain, and compared with a method for obtaining the air foam flooding recovery ratio through an indoor displacement experiment and oil reservoir numerical simulation, the method has the advantages of small workload and strong feasibility and operability. An effective technical method can be provided for evaluating and planning the development effect of the oil field.
Drawings
FIG. 1 is a schematic view of an air foam displacement recovery computing zone.
Detailed Description
In air foam flooding, the gas that makes up the foam gradually separates from the foaming system due to the instability of the foam itself. With the continuous alternating injection of gas and water-based foaming system solutions, it is assumed that the injected fluid will gradually form three zones within the formation, namely a foam zone, a liquid phase zone and a gas phase zone, due to differences in the fluid flow rate ratio within the formation. Because the gas fluidity is greater than the water-based solution fluidity and the water-based solution fluidity is greater than the foam fluidity, the foam region, the liquid phase region and the gas phase region are sequentially arranged from near to far from the injection well, as shown in fig. 1. In the context of figure 1 of the drawings,A foam 、A water andA gas respectively indicate the areas occupied by the formation of the foam region, the liquid phase region and the gas phase region,A btfoam 、A btwater andA btgas it means that the three regions can each expand the occupied area under the current implantation amount,A total representing the area of a complete well pattern.
According to the partition and the definition, the displacement stages are divided into before and after gas breakthrough, and then the displacement efficiency and the sweep efficiency of each region are respectively considered for calculation, and finally the recovery ratio of the air foam displacement in different stages is obtained. Before calculating the phase recovery, it is first determined at which phase the displacement is.
As shown in FIG. 1, whenA btfoam +A btwater +A btgas< A total When the sum of the swept areas of the three regions is smaller than the whole oil reservoir area, the gas is considered to be not broken through; when in useA btfoam +A btwater +A btgas= A total When the sum of the swept areas of the three regions occupies the whole oil reservoir, the gas is considered to break through at the moment; when in useA btfoam +A btwater= A total When the sum of the swept areas of the water-based liquid phase region and the foam region occupies the whole oil reservoir, the gas phase region is considered to be completely broken through; according to definition and seepage mechanics, the area of each region can be calculated by the following formula:
（1）
（2）
（3）
wherein, ①CIs a well pattern related coefficient; when a five-point well pattern is used,C= 0.718; when an inverted seven-point pattern is used,C= 0.743; when an inverse nine-point pattern is used,C=0.525；
②、andrespectively, the foam-crude oil mobility ratio, the foam liquid-crude oil mobility ratio and the gas-crude oil mobility ratio, which are respectively determined by the mobility ratios of the two fluids under homogeneous conditionsMAnd coefficient of permeability variationVAccording to the fitting relation of the wave and coefficients of the fluids with different fluidity ratios under the heterogeneous condition, the fitting relation is respectively calculated by the following formulas:
when in useV≤0.7When the temperature of the water is higher than the set temperature,
（4）
when in useV＞0.7When the temperature of the water is higher than the set temperature,
(5)
③ calculationA foam : firstly, calculating the residual foam amount by using the data of the foam half-life:
（6）
wherein,V left for a certain complete slug transit timetThe remaining volume of foam;V i the volume of a foam slug as it is formed is assumed in the calculation to be the sum of the volume of injected air and foaming system solution at formation pressure, thus the total injected volume of fluid for each slug;Tis the foam half-life; formula (6) represents a calculation method of the residual quantity of the single slug foam, and a working system of sectional injection is adopted on site, so that the residual quantity of the foam is calculated in a mode of accumulating a plurality of volumes of the foam which have passed different times. The moment of formation of each foam slug is calculated as the moment at which both fluids forming the slug have completed injection.Thus, in physical sense, the swept volume of the foam regionV foam The following can be calculated:
（7）
wherein,S wc irreducible water saturation;S orfoam is the residual oil saturation of the foam flooding, which is equal to the endpoint value when the relative permeability of the foam and the crude oil in the relative permeability curve of the crude oil is 0;
after the swept volume of the foam zone was obtained, the swept area of the foam zone was as follows:
（8）
the swept area of the water-based liquid phase region, which is generated by the collapse of the foam, can be calculated from its physical significance by the following formula:
（9）
wherein,φin order to determine the porosity of the reservoir,hthe thickness of the oil reservoir is taken as the oil reservoir thickness,λ water representing the volume ratio of the foaming system solution in each injection slug,S orwater the residual oil saturation of the foam liquid flooding is equal to the endpoint value when the relative permeability of the foam liquid and the crude oil in the relative permeability curve of the crude oil is 0;
the swept area of the gas phase region comes from the air which can not form foam after the fluid is injected and the swept area formed by the gas generated after the foam is broken at the front edge part, and can be expressed as follows according to the physical meaning:
（10）
wherein,λ gas representing the volume ratio occupied by the gas in each injection slug,S orgas residual oil saturation for gas flooding, which is equal to the endpoint value when the relative permeability of the gas to crude oil in the relative permeability curve of the gas to crude oil is 0,Rindicating the reaction coefficient of the gas, known from low-temperature oxidationR=0.996。
After the displacement phase is determined, the pre-breakthrough and post-breakthrough recovery rates are considered and calculated, respectively.
(one) Pre-breakthrough recovery
The pre-breakthrough recovery comprises three parts, namely foam zone recovery, liquid zone recovery and gas zone recovery;
(1) the foam zone recovery calculation process is as follows: because the foam stable area is far smaller than the area of the oil reservoir and the profile control plugging effect is obvious, the foam area is a circular area with the well bottom as the circle center and small radius, and the breakthrough can not be caused all the time. Before breakthrough, the injection volume multiple is equal to the sweep coefficient, so the sweep volume is equal to the volume of injected foam;
① calculating sweep coefficients
Ev foam = Ez foam ×Es foam （11）
Wherein,Es foam is the plane sweep coefficient of the foam area,Ez foamm longitudinal sweep efficiency of the foam zone
（12）
（13）
Wherein,Mis the ratio of the fluidity of the foam to the crude oil,is the ratio of viscous force to gravity
（14）
In the formula,μ t the permeation speed of the foam is shown,μ 0 in order to be the viscosity of the crude oil in the formation,χthe distance of the oil reservoir along the direction of water injection,K x for transverse permeability, Δ ρ is the density difference of the displacement fluid and the displaced fluid;
② calculating Displacement efficiency
Because the foam can play an obvious role in plugging and profile control in the air foam displacement, the foam displacement is assumed to be piston type displacement in a foam area, and the displacement efficiency is highEd foam For constant value, it is determined by the following formula
（15）
In the formula,S oi is the original oil saturation;
③ calculated recovery ratio:
RF foam =Ed foam ×Ev foam （16）；
(2) the liquid phase area recovery ratio calculation process is as follows:
the volume sweep coefficient of the liquid phase region is as follows:
Ev water =Ez water ×Es water （17）
wherein,Es water is the planar sweep coefficient of the foam liquid,Ez water the longitudinal sweep coefficient of the foam liquid is shown;Ez water the fluidity ratio of the foaming system solution and the crude oil is substituted into the formula (13) for calculation;
（18）
according to the leading edge theory, the average displacement fluid saturation is always equal in the range before the leading edge reaches the production well and before the leading edge, thus the foam fluid dynamic displacement efficiency is equal before breakthroughEd water Should be constant, is determined by
（19）
Liquid phase zone recoveryRF water Comprises the following steps:
RF water = Ed water ×Ev water （20）
(3) the gas phase zone recovery calculation process is as follows:
the volume sweep efficiency of the gas phase region is as follows:
Ev gas =Ez gas ×Es gas （21）
wherein,Es gas is the planar sweep coefficient of the foam liquid,Ez gas the longitudinal sweep coefficient of the foam liquid is shown;Ez gas the fluidity ratio of the gas and the crude oil is substituted into the formula (13) for calculation;
（22）
（23）
recovery of gas phase zoneRF gas Comprises the following steps:
RF gas = Ed gas ×Ev gas （24）
the total recovery ratio before gas breakthrough is as follows:
RF= RF foam ＋RF water ＋RF gas 。
(II) recovery after breakthrough
(1) Calculating the volume sweep coefficient:
a: aiming at homogeneous oil reservoirs, the plane sweep coefficient when the oil reservoir engineering method is broken through is calculated by adopting the following formulaEs bt The following formula:
（25）
broken plane sweep coefficientEs afterbt The following formula:
（26）
wherein,Dfor coefficients relating to the pattern type, when a five-point pattern is used,D=0.2749(ii) a When an inverted seven-point pattern is used,D =0.2351(ii) a When an inverse nine-point pattern is used,D=0.201；V ibt volume of injected fluid for breakthrough;
b: aiming at the non-homogeneous oil reservoir,calculating the plane sweep coefficient by correcting the mobility ratio in the homogeneous reservoir formula, and introducing a pseudo-mobility ratio M which respectively comprises the pseudo-mobility ratios of foam and crude oilFoam concentrate and crude oil fluidity ratioAnd the pseudo-fluidity ratio of the gas and the crude oilCalculating the planar wave sum coefficients of the foam region, the liquid phase region and the gas phase region respectively when the breakthrough occurs
The calculation is the same as the above equations (4) and (5); plane sweep coefficient at break throughEs bt The following formula:
（27）
broken plane sweep coefficientEs afterbt The following formula:
（28）
wherein the coefficientsUsed for limiting the planar sweep coefficient after breakthrough to lead the planar sweep coefficient to tend to the maximum planar sweep coefficient under the conditions of the current fluidity ratio and the permeability coefficient of variationEs max The calculation method is as follows:
（29）
calculate the bestLarge plane sweep coefficientEs max Before, firstly, the value of the boundary point when the permeability variation coefficient changes from low to high is introducedV c The relationship between the fluidity ratio and the fluidity ratio can be calculated by the following formula:
（30）
coefficient of permeability variationV＜V c When the maximum plane sweep efficiency is as follows,
（31）
coefficient of permeability variationV≥V c The maximum plane sweep coefficient is
（32）。
WhereinEs c The coefficient of permeability variation is equal toV c The plane sweep coefficient.
Longitudinal sweep coefficientEz afterbt The calculation method is the same as the formula (13);
volume sweep coefficient
Ev afterbt =Ez afterbt ×Es afterbt （33）；
(2) Calculating dynamic oil displacement efficiencyE d Comprises the following steps:
（34）
wherein,S d in order to displace the fluid dynamic saturation,for residual oil saturation at dynamic displacement,；
according to the theory of water saturation of the front edge of the seepage mechanics, the volume multiple of the injected pores is accumulatedPVIs the inverse of the rate of change of water content to water saturation, i.e.
（35）
Meanwhile, according to the theory of seepage mechanics, the water contentf w Can be expressed as:
（36）
according to the relative permeability of two phases of oil and foam liquidK ro AndK rw is a function of the water saturation, which in turn can be generally expressed as:
（37）
whereina、bAs a coefficient, can be obtained byAndlinear regression is carried out on the semilogarithmic coordinate graph;
substituting formula (37) for formula (36) and deriving to obtain
（38）
（39）
The cumulative injection pore volume multiple may be determined from the cumulative amount of injection fluid, i.e.:
（40）
whereinB w Is the volume factor of the formation water,Athe area of the oil-containing layer is,hthe thickness of the oil reservoir is taken as the oil reservoir thickness,φin order to determine the porosity of the reservoir,ρ w is the density of the foam liquid;
the given value can be obtained by using the above formulaPVThe corresponding water content at the moment can be obtained according to the fluidity ratio of the number; then according to the seepage mechanics water phase flow-dividing formula, the dynamic average water saturation at the moment can be obtainedI.e. dynamic saturation of the displacement fluidS d Namely:
（41）
wherein,μ w the viscosity of the foam concentrate is used as the viscosity of the foam concentrate,μ 0 is the formation crude oil viscosity;
the oil displacement efficiency is substituted into a formula (34) of the oil displacement efficiency, and the dynamic average oil displacement efficiency of the oil deposit at the moment can be obtained:
（42）
(3) calculated recovery ratio
Obtaining the recovery ratio according to the calculated volume sweep coefficient and the oil displacement efficiencyRFThe calculation is as follows:
RF=Ed×Ev（43）。
example 1
The method for predicting the recovery ratio of the air foam flooding of the oil reservoir is verified by applying the actual production data of the oil field:
the Tang 80 well region is located in Zhengji Zhengzhou of Yanan city of Shanxi province, the main oil-containing layer is a three-fold-system extended-group-length 6-oil-layer group, the average buried depth of the oil reservoir is 441 m, the average porosity is 7.9%, and the average permeability is 0.82 multiplied by 10-3μm2The pressure coefficient of an original stratum is 0.95, the temperature of an oil layer is 26-30 ℃, and the method belongs to an ultra-low permeability, low pressure and low temperature lithologic oil reservoir. And (4) determining to carry out an air foam flooding mine test in the region through oil reservoir screening and analysis. Before the mine field test, a large number of indoor tests and evaluation studies have been conducted on the area, and relatively comprehensive parameter data are obtained, as detailed in table 1.
TABLE 1 Tang 80 well indoor test parameter values (under formation conditions)
On the basis of indoor comprehensive research, preferably selecting a 54-well cluster and a 55-well cluster in the area to carry out air injection foam flooding mine field test, wherein the oil-containing area of the well cluster is 0.58km2The effective thickness of the oil layer group is 10 m. The foam liquid is injected into the foam tank for 494.27m3Cumulative air injection 528.34m3(volume under stratum condition) after the benefited oil well begins to see gas, air foam is calculated according to the accumulated oil production data on siteThe recovery ratio in the flooding stage is 1.79 percent. When the statistical data is up, the foam liquid 5909.32m is injected in an accumulated way3Cumulative air injection 20209.24m3(volume under stratum condition), the well group is always in the gas-visible stage, and the recovery ratio in the air foam flooding stage is calculated to reach 7.61% according to the accumulated oil production data on site.
According to the table 1 and the related parameters, the method for predicting the recovery ratio of the air foam flooding of the oil reservoir is used for predicting and calculating the recovery ratio of the well group in different stages of air foam flooding, and foam liquid 494.27m is injected in an accumulated mode before the gas is seen3Cumulative air injection 528.34m3(volume under formation conditions) the recovery factor was calculated to be 1.92%; the foam liquid is injected into the foam tank for 5909.32m3Cumulative air injection 20209.24m3The recovery factor (volume under formation conditions) was calculated to be 8.26%. The absolute errors of the two prediction calculation results and the field actual data calculation result are respectively 0.13% and 0.65%, and the relative errors are respectively 7.26% and 8.54%, so that the accuracy requirement that the relative error is controlled within 10% in engineering calculation is met. The accuracy and the applicability of the method for predicting the recovery ratio of the air foam flooding of the oil reservoir are explained, and a basis and a reference can be provided for evaluation of the air foam flooding effect of the oil reservoir and related planning.
The meanings represented by the respective physical quantities mentioned above have been explained, and the specific units are as follows:A foam 、A water 、A gas 、A btfoam 、A btwater 、A btgas 、A total 、Athe units with equal area are all square meters;V i 、V left 、V ibt 、V foam units of equal volume are ㎥;μ w andμ 0 the units of equal viscosity are(ii) a Δ ρ andρ w of equal densityUnits are all㎏/㎥；hThe units of the spatial scales such as chi and the like are m;μ t unit is m/d；K x Unit of (d) is md;Tin units of min. Fluidity ratio parameter、、、MSaturation parameterS wc 、S oi 、S orfoam 、S owater 、S orgas 、、S d 、Coefficient of spreadEv foam 、Es foam 、Ez foam 、Ev water 、Es water 、Ez water 、Es gas 、Ez gas 、Es bt 、Es afterbt 、Es max 、Es c 、Ev、Es、EzEfficiency of oil displacementEd foam 、Ed water 、Ed gas 、EdRecovery ratio of oilRF foam 、RF water 、RF gas 、RFAnd are andB w 、φ、PV、K ro 、K rw 、fwthe isoparametric are dimensionless.
Claims (5)
1. A method for predicting the recovery ratio of air foam flooding of an oil reservoir is characterized by comprising the following steps: the method comprises the following steps:
(1) assuming that the injected fluid can gradually form three areas, namely a foam area, a liquid phase area and a gas phase area, and dividing the displacement stage into a certain stage of the displacement stage before gas breakthrough and a certain stage after gas breakthrough;
(2) respectively calculating the displacement efficiency and the sweep efficiency of each area of the foam area, the liquid phase area and the gas phase area in the current stage before or after the current stage is determined to be gas breakthrough;
(3) recovery ratio R = displacement efficiency × sweep efficiency.
2. The method for predicting reservoir air foam flooding recovery of claim 1, wherein:A btfoam +A btwater +A btgas< A total when the sum of the swept areas of the three regions is smaller than the whole oil reservoir area, the gas is considered to be not broken through;A btfoam +A btwater +A btgas= A total when the sum of the swept areas of the three regions occupies the whole oil reservoir, the gas is considered to break through at the moment; when in useA btfoam +A btwater= A total When the sum of the swept areas of the water-based liquid phase region and the foam region occupies the whole oil reservoir, the gas phase region is considered to be completely broken through; according to definition and seepage mechanics, the area of each region can be calculated by the following formula:
（1）
（2）
（3）
wherein, ①CIs a well pattern related coefficient; when a five-point well pattern is used,C= 0.718; when an inverted seven-point pattern is used,C= 0.743; when an inverse nine-point pattern is used,C=0.525；
②、andrespectively, the foam-crude oil mobility ratio, the foam liquid-crude oil mobility ratio and the gas-crude oil mobility ratio, which are respectively determined by the mobility ratios of the two fluids under homogeneous conditionsMAnd coefficient of permeability variationVAccording to the fitting relation of the wave and coefficients of the fluids with different fluidity ratios under the heterogeneous condition, the fitting relation is respectively calculated by the following formulas:
when in useV≤0.7When the temperature of the water is higher than the set temperature,
（4）
when in useV＞0.7When the temperature of the water is higher than the set temperature,
（5）
③ calculationA foam : firstly, calculating the residual foam amount by using the data of the foam half-life:
（6）
wherein,V left for a certain complete slug transit timetThe remaining volume of foam;V i the volume of a foam slug as it is formed is assumed in the calculation to be the sum of the volume of injected air and foaming system solution at formation pressure, thus the total injected volume of fluid for each slug;Tis the foam half-life;
swept volume of the foam zoneV foam The following can be calculated:
（7）
wherein,S wc irreducible water saturation;S orfoam is the residual oil saturation of the foam flooding, which is equal to the endpoint value when the relative permeability of the foam and the crude oil in the relative permeability curve of the crude oil is 0;
the swept area of the foam zone is as follows:
（8）
the swept area of the water-based liquid phase region, which is generated by the collapse of the foam, can be calculated from its physical significance by the following formula:
（9）
wherein,φin order to determine the porosity of the reservoir,hthe thickness of the oil reservoir is taken as the oil reservoir thickness,λ water representing the volume ratio of the foaming system solution in each injection slug,S orwater the residual oil saturation of the foam liquid flooding is equal to the endpoint value when the relative permeability of the foam liquid and the crude oil in the relative permeability curve of the crude oil is 0;
the swept area of the gas phase region comes from the air which can not form foam after the fluid is injected and the swept area formed by the gas generated after the foam is broken at the front edge part, and can be expressed as follows according to the physical meaning:
（10）
wherein,λ gas representing the volume ratio occupied by the gas in each injection slug,S orgas residual oil saturation for gas flooding, which is equal to the endpoint value when the relative permeability of the gas to crude oil in the relative permeability curve of the gas to crude oil is 0,Rindicating the reaction coefficient of the gas, known from low-temperature oxidationR=0.996。
3. The method for predicting reservoir air foam flooding recovery of claim 2, wherein: the calculation of the recovery ratio before breakthrough comprises three parts, namely the recovery ratio of a foam zone, the recovery ratio of a liquid zone and the recovery ratio of a gas zone;
wherein the foam area recovery ratio calculation process is as follows:
① calculating sweep coefficients
Ev foam = Ez foam ×Es foam （11）
Wherein,Es foam is the plane sweep coefficient of the foam area,Ez foam longitudinal sweep efficiency of the foam zone
（12）
（13）
Wherein,Mis the ratio of the fluidity of the foam to the crude oil,is the ratio of viscous force to gravity
（14）
In the formula,μ t the permeation speed of the foam is shown,μ 0 in order to be the viscosity of the crude oil in the formation,χthe distance of the oil reservoir along the direction of water injection,K x for transverse permeability, Δ ρ is the density difference of the displacement fluid and the displaced fluid;
② calculating Displacement efficiency
（15）
In the formula,S oi is the original oil saturation;
③ calculated recovery ratio:
RF foam =Ed foam ×Ev foam （16）；
similarly, the liquid phase region recovery process is as follows:
Ev water =Ez water ×Es water （17）
wherein,Es water is the planar sweep coefficient of the foam liquid,Ez water the longitudinal sweep coefficient of the foam liquid is shown;Ez water the fluidity ratio of the foaming system solution and the crude oil is substituted into the formula (13) for calculation;
（18）
（19）
liquid phase zone recoveryRF water Comprises the following steps:
RF water = Ed water ×Ev water （20）
similarly, the gas phase zone recovery process is as follows:
Ev gas =Ez gas ×Es gas （21）
wherein,Es gas is a planar sweep coefficient of the gas,Ez gas is the longitudinal sweep coefficient of the gas;Ez gas the fluidity ratio of the gas and the crude oil is substituted into the formula (13) for calculation;
（22）
（23）
recovery of gas phase zoneRF gas Comprises the following steps:
RF gas = Ed gas ×Ev gas （24）
the total recovery ratio before gas breakthrough is as follows:
RF= RF foam ＋RF water ＋RF gas 。
4. the method for predicting reservoir air foam flooding recovery of claim 3, wherein: the recovery ratio after breakthrough comprises three parts, namely foam zone recovery ratio, liquid zone recovery ratio and gas zone recovery ratio;
(1) calculating the volume sweep coefficient:
plane sweep coefficient in breakthrough for homogeneous reservoirEs bt The following formula:
（25）
broken plane sweep coefficientEs afterbt The following formula:
（26）
wherein,Dfor coefficients relating to the pattern type, when a five-point pattern is used,D=0.2749(ii) a When an inverted seven-point pattern is used,D =0.2351(ii) a When an inverse nine-point pattern is used,D=0.201；V ibt volume of injected fluid for breakthrough;
plane sweep coefficient in breakthrough for heterogeneous reservoirEs bt The following formula:
（27）
broken planeSweep coefficientEs afterbt The following formula:
（28）
wherein the coefficientsUsed for limiting the planar sweep coefficient after breakthrough to lead the planar sweep coefficient to tend to the maximum planar sweep coefficient under the conditions of the current fluidity ratio and the permeability coefficient of variationEs max The calculation method is as follows:
（29）
longitudinal sweep coefficient after breakthroughEz afterbt The calculation method is the same as the formula (13);
volume sweep coefficient
Ev afterbt =Ez afterbt ×Es afterbt （33）；
(2) Calculating dynamic oil displacement efficiencyE d Comprises the following steps:
（34）
wherein,S d in order to displace the fluid dynamic saturation,for residual oil saturation at dynamic displacement,；
according to the theory of water saturation of the front edge of the seepage mechanics, the volume multiple of the injected pores is accumulatedPVIs the inverse of the rate of change of water content to water saturation, i.e.
（35）
Meanwhile, according to the theory of seepage mechanics, the water contentf w Can be expressed as:
（36）
according to the relative permeability of two phases of oil and foam liquidK ro AndK rw is a function of the water saturation, which in turn can be generally expressed as:
（37）
whereina、bAs a coefficient, can be obtained byAndlinear regression is carried out on the semilogarithmic coordinate graph;
substituting formula (37) for formula (36) and deriving to obtain
（38）
（39）
The cumulative injection pore volume multiple may be determined from the cumulative amount of injection fluid, i.e.:
（40）
whereinB w Is the volume of formation waterThe coefficients of which are such that,Athe area of the oil-containing layer is,hthe thickness of the oil reservoir is taken as the oil reservoir thickness,φin order to determine the porosity of the reservoir,ρ w is the density of the foam liquid;
the given value can be obtained by using the above formulaPVThe corresponding water content at the moment can be obtained according to the fluidity ratio of the number; then according to the seepage mechanics water phase flow-dividing formula, the dynamic average water saturation at the moment can be obtainedI.e. dynamic saturation of the displacement fluidS d Namely:
（41）
wherein,μ w the viscosity of the foam concentrate is used as the viscosity of the foam concentrate,μ 0 is the formation crude oil viscosity;
the oil displacement efficiency is substituted into a formula (34) of the oil displacement efficiency, and the dynamic average oil displacement efficiency of the oil deposit at the moment can be obtained:
（42）
(3) calculated recovery ratio
Obtaining the recovery ratio according to the calculated volume sweep coefficient and the oil displacement efficiencyRFThe calculation is as follows:
RF=Ed×Ev（43）。
5. the method for predicting reservoir air foam flooding recovery of claim 4, wherein: saidEs max The calculation method of (2) is as follows:
value at the cut-off point when the permeability coefficient of variation changes from low to high is introducedV c The relationship between the fluidity ratio and the fluidity ratio can be calculated by the following formula:
（30）
coefficient of permeability variationV＜V c When the maximum plane sweep efficiency is as follows,
（31）
coefficient of permeability variationV≥V c The maximum plane sweep coefficient is
（32）。
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