CN104100263A - Method for determining residual oil saturation of non-uniform water flooded layer - Google Patents
Method for determining residual oil saturation of non-uniform water flooded layer Download PDFInfo
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- CN104100263A CN104100263A CN201310523076.8A CN201310523076A CN104100263A CN 104100263 A CN104100263 A CN 104100263A CN 201310523076 A CN201310523076 A CN 201310523076A CN 104100263 A CN104100263 A CN 104100263A
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Abstract
The invention provides a method for determining residual oil saturation of a non-uniform water flooded layer, and belongs to the technical field of geophysical logging evaluation of reservoir saturation. A non-uniform water flooded layer saturation equivalent model diagram is established by an equivalent area method, and a method for determining residual oil saturation by production profile data is corrected to obtain the method for determining the residual oil saturation of the non-uniform water flooded layer; the obtained residual oil saturation of the non-uniform water flooded layer better reflects the overall residual oil saturation of the water flooded layer, and is more consistent with the actual situation of a reservoir, thus achieving accurate knowledge of the regional residual oil saturation distribution law, and providing a scientific basis for reasonable and efficient development of the reservoir.
Description
Technical field
The present invention relates to geophysical log and evaluate reservoir saturation ratio technical field, be specially a kind of definite method of non-homogeneous Water Flooding Layer remaining oil saturation.
Background technology
The definite of individual well remaining oil saturation is the basis of oil field development oil reservoir in period Study on residual oil distribution, after cover, remaining oil saturation monitoring is the means that extensively adopt both at home and abroad at present, but after cover, saturation ratio detector cannot be applicable to high temperature, high pressure reservoir, simultaneously in oil field old, stepout well is limited, can not only rely on completion combination logging data and determine remaining oil saturation.Existing solution is to utilize production profile data to determine remaining oil saturation.
According to teaching material " production logging principle and data interpretation " (Guo Haimin, Dai Jiacai, 2007, 270～272), utilize the production logging production profile data of Water Flooding Layer, be that intermediate variable can be set up producing water ratio and the stratum relational expression in the remaining oil saturation at well point place in conjunction with LEVERETT equation with oil-water relative permeability, this relational expression of profit can obtain the Core analysis of water saturation and producing water ratio, for a certain oil field, utilize production profile data can obtain longitudinal producing water ratio at single well point place, determine the water saturation at well point place by looking into plate, and then obtain Water Flooding Layer remaining oil saturation.
For continental reservoir, the variation of the inhomogeneous and sedimentary rhythm of the lithology of reservoir, physical property, must cause the water flooding degree of oil reservoir inhomogeneous.Determining by production profile data in the process of Water Flooding Layer remaining oil saturation, find by the completion combination logging data comparative analysis to production profile and different times, production profile demonstration is only produced the layer of water and is not meant that the remaining oil saturation of this layer necessarily approaches residual oil saturation, in the time that the non-homogeneous water logging of reservoir is serious, can only reflect that this layer of local remaining oil saturation approaches residual oil saturation, other position may also have movable remaining oil saturation, this situation in non-homogeneous water logging, thick-layer reflection is more obvious.
Fig. 1 is the deep induction resistivity comparison diagram of the same substratum in Dong Pu depression Wen Dong oil field at adjacent well different times.The data that when W13-418 well is this well finishing drilling, on March 31st, 2005 records, in sand three, No. 41 layer depth induction motors of 8 sand groups obviously show the strong feature of bottom water logging, and a little less than the water flooding degree of top.Be adjacent and W13-388 well that construction location of living in is close, W13-212 well, W13-315 well is respectively in April, 2000, in January, 1991 and in October, 1987 completion well logging, W13-388 well respective layer show be characterized as bottom water logging strong, the respective layer of W13-212 and W13-315 well is oil reservoir, contrasting these 4 mouthfuls of wells can find out, along with the passing of development time, resistivity is lowering gradually, the non-homogeneous Flooding Characteristics of reservoir is obvious, once breaking through, injected water forms water channel, a little less than flood position remaining oil will obviously be lowered by the effect of displacement, the Water Flooding Layer remaining oil saturation that uses the method for prior art to try to achieve can only show by the position remaining oil saturation of water breakthrough, be approximately equal to residual oil saturation, in this case, conventionally be judged as this layer and there is no moveable oil, and in fact, the non-homogeneous water logging effect of bringing due to reservoir, this reservoir should also have part moveable oil, be that well point place remaining oil saturation is actually and is greater than the Water Flooding Layer remaining oil saturation of trying to achieve by art methods.Therefore, only utilize the definite Water Flooding Layer remaining oil saturation of production profile data can only reflect the remaining oil saturation of strong Water out zone, be difficult to the remaining oil saturation of the relatively weak Water out zone of reflection, cause the definite Water Flooding Layer remaining oil saturation entirety of the method less than normal, can not accurately reflect the actual conditions of reservoir.
Summary of the invention
The object of the invention is to overcome existing method utilizing production profile data to determine in the process of remaining oil saturation, fail to consider the heterogeneity of Water Flooding Layer water flooding degree, make definite Water Flooding Layer remaining oil saturation less than normal, differ larger defect with reservoir actual conditions, provide a kind of non-homogeneous Water Flooding Layer remaining oil saturation to determine method.It specifically comprises the following steps:
1, utilize the production profile data of Water Flooding Layer to determine the producing water ratio of Water Flooding Layer, set up producing water ratio and the stratum relation in the remaining oil saturation at well point place.
2, utilize water drive oil phase to ooze experimental data and determine irreducible water saturation, residual oil saturation and water oil viscosity ratio.
3, adopt Multielement statistical analysis method and mathematical inversion to process the relation of determining block producing water ratio and water saturation, set up the Core analysis of producing water ratio and water saturation.
4, by searching the Core analysis of producing water ratio and water saturation, determine Water Flooding Layer remaining oil saturation.
5, utilize the definite Water Flooding Layer remaining oil saturation of step 4, build non-homogeneous Water Flooding Layer saturation ratio equivalent model figure, set up the original relational expression that contains saturation ratio, Water Flooding Layer remaining oil saturation and Water Flooding Layer thickness proportion coefficient of non-homogeneous Water Flooding Layer average residual oil saturation and Water Flooding Layer, and determine thus the remaining oil saturation of corresponding non-homogeneous Water Flooding Layer.Wherein, the initial oil saturation of Water Flooding Layer is determined by initial stage of development completion well-log information.
Use the definite method of a kind of non-homogeneous Water Flooding Layer remaining oil saturation provided by the invention, by building non-homogeneous Water Flooding Layer saturation ratio equivalent model figure, revise production profile data and determined the method for remaining oil saturation, obtain a kind of definite method of non-homogeneous Water Flooding Layer remaining oil saturation, the non-homogeneous Water Flooding Layer remaining oil saturation of trying to achieve more can reflect the overall remaining oil saturation of Water Flooding Layer, more be consistent with the actual conditions of reservoir, and then realize and accurately grasp the region remaining oil saturation regularity of distribution, for the reasonable effective exploitation of oil reservoir provides scientific basis.
Brief description of the drawings
Fig. 1 is the same substratum different times resistivity comparison diagram in adjacent well that utilizes prior art establishment;
Fig. 2 is technical solution of the present invention FB(flow block);
Fig. 3 is the non-homogeneous Water Flooding Layer saturation ratio equivalent model figure that utilizes the present invention to work out;
Fig. 4 is the 13 producing water ratio f of literary composition that utilize the present invention to work out
wwith water saturation S
wcore analysis;
Fig. 5 is the graph of a relation that floods by force layer thickness factor of proportionality σ and water logging layer thickness H that the present invention sets up.
Detailed description of the invention
Determine in the process of non-homogeneous Water Flooding Layer remaining oil saturation utilizing production profile data, the different parts water flooding degree of Water Flooding Layer is non-homogeneous, the Water Flooding Layer remaining oil saturation of trying to achieve by existing method often only reflects the remaining oil saturation of strong Water out zone, in order to obtain accurately non-homogeneous Water Flooding Layer remaining oil saturation, the present invention proposes a kind of definite method of non-homogeneous Water Flooding Layer remaining oil saturation.
The Wen Dong oil field of Dong Pu depression is typical high temperature, high pressure, high salt low-permeability oil deposit, and old liberated area development plan is adjusted, and stepout well is fewer and feweri, utilizes open hole well data to determine that remaining oil saturation is also restricted.Below in conjunction with the drawings and specific embodiments, the present invention is further described in detail.
As shown in Figure 2, the present invention includes following steps:
1, utilize the production profile data of Water Flooding Layer to determine the producing water ratio of Water Flooding Layer, set up producing water ratio and the stratum relation in the remaining oil saturation at well point place: utilize well completion data and the product of 299 non-homogeneous Water Flooding Layer of the 22 mouthfuls of wells in literary composition three sections of layer positions of 13 blocks of sand, Wen Dong oil field of Dong Pu depression to cut open data, determine the producing water ratio of Water Flooding Layer, can set up producing water ratio and stratum in the relation of the wet oil saturation ratio at well point place as the formula (1) in conjunction with LEVERETT equation:
In formula, f
wit is producing water ratio; μ
o, μ
wbe respectively the viscosity of oil and water; S
w, S
wi, S
orbe respectively stratum water saturation, irreducible water saturation and residual oil saturation; A, m, n are the factor of proportionality relevant to oil-water relative permeability.
The remaining oil saturation S of payzone
0with water saturation S
wpass be
S
o=100-S
w(2) also set up producing water ratio and the stratum relation in the remaining oil saturation at well point place.
2, utilize water drive oil phase to ooze experimental data and determine irreducible water saturation, residual oil saturation and water oil viscosity ratio: by 3 mouthfuls of well water displacement of reservoir oils in 13 22 mouthfuls of three sections of layer positions of sand wells of Wen Dong oil field literary composition are oozed to test data analysis mutually, 50 sample point experimental datas of representational 5 rock samples are screened, its irreducible water saturation, residual oil saturation average are respectively 26.73%, 27.35%, water oil viscosity ratio
be 0.2639.
3, adopt Multielement statistical analysis method and mathematical inversion to process the relation of determining block producing water ratio and water saturation, set up the Core analysis of producing water ratio and water saturation: adopt Multielement statistical analysis method by mathematical inversion processing, obtain regional experience coefficient a=1, m=3.6, n=2.8.The relational model of 13 producing water ratios of literary composition and water saturation is
The index of correlation that 50 sample point analytical calculations of test data are oozed in 3 mouthfuls of well water displacement of reservoir oils in 13 22 mouthfuls of wells of literary composition in applying step 2 is mutually 0.8894, and the water saturation mean absolute error of calculating is 0.0325(decimal), average relative error 5.61%.
Relation between water saturation and producing water ratio is subject to
s
wi, S
orthe impact of parameter value, under formation condition
be subject to the impact of the factors such as strata pressure, gas-oil ratio, formation water and change S
wiand S
orthe variation that is subject to reservoir lithology, physical property also there are differences.The relation of producing water ratio and water saturation often cannot be reflected with one or two plate in whole study area comprehensively, need to set up multiple plates by changing the value of viscosity ratio of oil and water, irreducible water saturation and residual oil saturation, Fig. 4 be civilian 13 at fixing S
wiand S
orsituation under, by changing the producing water ratio that does of viscosity ratio of oil and water and the Core analysis of water saturation.
4, by searching the Core analysis of producing water ratio and water saturation, determine Water Flooding Layer remaining oil saturation: utilize the production profile data can be in the hope of the aquifer yield of Water Flooding Layer, can calculate the producing water ratio of Water Flooding Layer, and then can search plate by producing water ratio and try to achieve corresponding water saturation.Just obtain Water Flooding Layer remaining oil saturation S by formula (2)
0.
5, utilize the definite Water Flooding Layer remaining oil saturation of step 4, build non-homogeneous Water Flooding Layer saturation ratio equivalent model figure by the algorithm of area equivalent, as shown in Figure 3, set up the original relational expression that contains saturation ratio, Water Flooding Layer remaining oil saturation and Water Flooding Layer thickness proportion coefficient of non-homogeneous Water Flooding Layer average residual oil saturation and Water Flooding Layer according to Fig. 3, and determine thus the remaining oil saturation of corresponding non-homogeneous Water Flooding Layer: in illustraton of model, setting pay thickness is H, and it is H that payzone floods by force position thickness
f, other positions (H-H
f) water logging relatively a little less than, the well-log information of this interval of exploitation initial stage or ooze mutually data statistics analyse and obtain the initial oil saturation S of Water Flooding Layer
oi.
The remaining oil saturation of flooding by force interval thinks that equaling production profile material computation goes out Water Flooding Layer remaining oil saturation S
o, the remaining oil saturation of the relatively weak interval of water logging is except S
ooutward, some movable remaining oil saturation.Carry out area equivalent processing according to above-mentioned illustraton of model, establish that to flood by force the ratio that interval accounts for Water Flooding Layer thickness be σ, the value of σ is relevant with the non-homogeneous character of reservoir.:
σ=H
fthe non-homogeneous Water Flooding Layer average residual of/H (4) oil saturation
computational methods are shown below:
On stricti jurise, say, the thickness proportion factor sigma of each Water Flooding Layer is not identical, but being subject to the restriction of longitudinal frame, production profile data often can not reflect this value, statistical analysis is found, σ value and the water logging layer thickness H of region interval present certain exponential relationship, according to bed thickness priority principle, choose 26 non-homogeneous Water Flooding Layer in 299 Water Flooding Layer of literary composition three sections of layer positions of 13 blocks of sand 22 mouthfuls of wells, add up each individual layer and flood by force layer thickness factor of proportionality σ, mainly be distributed in 26.7～60.0% scopes, average value 37.6%, set up the graph of a relation that floods by force layer thickness factor of proportionality σ and water logging layer thickness H, as shown in Figure 5.Make factor of proportionality σ be converted to the function of water logging layer thickness H by Fitting Analysis
σ＝H
-0.6705 （6）
The original relation that contains saturation ratio, produces Water Flooding Layer remaining oil saturation and pay thickness that non-homogeneous Water Flooding Layer average residual oil saturation is converted to Water Flooding Layer, obtains the non-homogeneous Water Flooding Layer remaining oil saturation of civilian 13 block computation model
Can be determined the remaining oil saturation of non-homogeneous Water Flooding Layer by formula (7) computation model.
Apply the definite method of this non-homogeneous Water Flooding Layer remaining oil saturation by interval in civilian 13 block sand three, calculate the remaining oil saturation of each sand group and with method correction before remaining oil saturation comparative analysis as shown in table 1.
Contrast table before and after the correction of table 1 remaining oil saturation method
Before utilizing remaining oil saturation average that the present invention tries to achieve by method correction 45.3% is increased to 51.0%, 5.7 percentage points are on average increased, more can reflect the overall remaining oil saturation of Water Flooding Layer through the non-homogeneous Water Flooding Layer remaining oil saturation of method corrected Calculation, more be consistent with the actual conditions of reservoir.Can realize thus the accurate grasp region remaining oil saturation regularity of distribution, for the reasonable effective exploitation of this block oil reservoir provides scientific basis.
Claims (4)
1. a definite method for non-homogeneous Water Flooding Layer remaining oil saturation, is characterized in that comprising the following steps:
(1) utilize the production profile data of Water Flooding Layer to determine the producing water ratio of Water Flooding Layer, set up producing water ratio and the stratum relation in the remaining oil saturation at well point place;
(2) utilize water drive oil phase to ooze experimental data and determine irreducible water saturation, residual oil saturation and water oil viscosity ratio;
(3) adopt Multielement statistical analysis method and mathematical inversion to process the relation of determining block producing water ratio and water saturation, set up the Core analysis of producing water ratio and water saturation;
(4) by searching the Core analysis of producing water ratio and water saturation, determine Water Flooding Layer remaining oil saturation;
(5) utilize the definite Water Flooding Layer remaining oil saturation of step (4), build non-homogeneous Water Flooding Layer saturation ratio equivalent model figure, set up the original relation that contains saturation ratio, Water Flooding Layer remaining oil saturation and Water Flooding Layer thickness proportion coefficient of non-homogeneous Water Flooding Layer average residual oil saturation and Water Flooding Layer, and determine thus the remaining oil saturation of corresponding non-homogeneous Water Flooding Layer.
2. a kind of definite method of non-homogeneous Water Flooding Layer remaining oil saturation according to claim 1, is characterized in that: the initial oil saturation of Water Flooding Layer is determined by initial stage of development completion well-log information.
3. the non-homogeneous Water Flooding Layer remaining oil saturation of one according to claim 1 is determined method, it is characterized in that: non-homogeneous Water Flooding Layer saturation ratio equivalent model figure builds by the algorithm of area equivalent.
4. according to definite method of a kind of non-homogeneous Water Flooding Layer remaining oil saturation described in claim 1,2 or 3, it is characterized in that: the original relational expression that contains saturation ratio, Water Flooding Layer remaining oil saturation and Water Flooding Layer thickness proportion coefficient of non-homogeneous Water Flooding Layer average residual oil saturation and Water Flooding Layer is
In formula, S
ofor Remaining Oil Distribution in Single Layer saturation ratio; S
oifor the initial oil saturation of Water Flooding Layer; σ is the factor of proportionality that floods by force interval and account for Water Flooding Layer thickness, σ=H
f/ H=H
b, H is Water Flooding Layer thickness, H
ffor Water Flooding Layer is flooded by force position thickness, because each Water Flooding Layer σ value is not identical, and the σ value of region interval and water logging layer thickness H present certain exponential relationship, final, Fitting Analysis makes factor of proportionality σ be converted to the function of water logging layer thickness H, and b is the exponential term that Fitting Analysis obtains.
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| CN104747154A (en) * | 2015-03-05 | 2015-07-01 | 中国石油天然气股份有限公司 | Method for using oil displacement efficiency ratios for improving steam drive remaining oil research accuracy |
| CN105447762A (en) * | 2015-12-08 | 2016-03-30 | 中国石油天然气集团公司 | Calculation method for low permeability reservoir flooding information of fluid replacement |
| CN107038266A (en) * | 2016-02-04 | 2017-08-11 | 中石化石油工程技术服务有限公司 | The new saturation degree method for establishing model of Water Flooding Layer based on digital cores |
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