CN108457646A - The method for determining properties of fluid in bearing stratum - Google Patents
The method for determining properties of fluid in bearing stratum Download PDFInfo
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- CN108457646A CN108457646A CN201710090936.1A CN201710090936A CN108457646A CN 108457646 A CN108457646 A CN 108457646A CN 201710090936 A CN201710090936 A CN 201710090936A CN 108457646 A CN108457646 A CN 108457646A
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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
- E21B49/08—Obtaining fluid samples or testing fluids, in boreholes or wells
- E21B49/087—Well testing, e.g. testing for reservoir productivity or formation parameters
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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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Abstract
A kind of method of determining properties of fluid in bearing stratum, including：The multiple reservoirs for selecting known fluid property in region to be measured choose multiple measurement points for each reservoir, obtain the deep resistivity and porosity of each measurement point；Each measurement point is ranked up by the apparant formation water resistivity and its evolution for calculating each measurement point of each reservoir from small to large according to its apparant formation water resistivity evolution, calculates the cumulative frequency of each measurement point after sequence；For each reservoir, cumulative frequency and its corresponding apparant formation water resistivity evolution based on each measurement point in reservoir carry out linear fit under normal probability paper coordinate system；Establish flow net model crossplot；The region with different fluid property is divided on flow net model crossplot；For reservoir to be identified, step 13 is repeated, according to the average pore of reservoir to be identified and linear fit as a result, determining the fluid properties of reservoir to be identified by flow net model crossplot.
Description
Technical field
The present invention relates to complicated reservoirs exploration and development field, more particularly to a kind of method of determining properties of fluid in bearing stratum.
Background technology
Determine that properties of fluid in bearing stratum is one of the important content of well log interpretation evaluation, reservoir lithology is more pure, physical property
It well, can be to reservoir institute with porosity cross plot using reservoir resistivity value or resistivity in the case that pore structure is single
Accurate judgement is made containing fluid properties.When reservoir is complex, interstitial space type is various, complex pore structure when, resistance
Rate value or resistivity and porosity cross plot recognition effect are undesirable.
For many years, well logging scientific research personnel has carried out lasting research to the fluid identification of complicated reservoirs, and (China is specially by Zhao Jianbin etc.
Sharp CN201510246298.9, patent name " a kind of clastic reservoir rock Fluid Identification Method based on array induction logging ") according to
Array induction slope characteristics parameter and relevant feature parameters cross plot are established according to formation testing conclusion point series, determines oil, gas and water boundary
Zone convection body carries out sentencing knowledge；(areas Liu Jun NE Sichuan YB Changxing Group-flies the group fluid identification of reservoir method evaluation of celestial pass to Liu Jun
[J] Changjiang University journal (natural science edition), 2011,8 (5)：31-33) utilize porosity and water saturation cross-plot,
The comprehensive identification Gas-Water Contant of the methods of normal distribution method, resistivity logging method of identification；(5 Yi, the such as Si Maliqiang, Wu Zhou such as 5 Yi
The Russian oil fields the UMD Kiels Ba Shi layer fluid recognition methods evaluation [J] Chongqing University of Science and Technology journal (natural science edition), 2013,
15(6)：21-24) use the methods of normal distribution method, resistivity and porosity cross-plot, dual porosity overlay method are comprehensive to know
The not oil field oil water layer；Xiao Li (INTERVAL FRACTURE LOG RESPONSE METHOD of Xiao Li micro-resisitivity images and the stream of carbonate reservoir
Volume property automatic identification research [D] Jilin University, 2005) using cross-plot, normal distribution method, dual porosity overlapping display
Oiliness method and indirect discrimination method are determined fluid properties.
Summarize the prior art, one of current widely used method is normal distribution method, but its be only through it is qualitative
The size judgement fluid properties of its slope are analyzed, Consideration is few, and accuracy is poor；The prior art seldom applies array induction to survey
The new loging technologies such as well；In addition, the prior art is poor for the computational accuracy of the parameters such as water saturation, fluid identification effect is influenced
Fruit.
Invention content
The purpose of the present invention is to provide a kind of methods of determining properties of fluid in bearing stratum, and Logging Curves can be applied accurate
Really judge properties of fluid in bearing stratum, improves evaluation precision.
The present invention uses following solution：
A kind of method of determining properties of fluid in bearing stratum, including：
Step 1：The multiple reservoirs for selecting known fluid property in region to be measured, are arranged multiple surveys in each reservoir respectively
Point is measured, the deep resistivity and porosity of each measurement point are obtained；
Step 2：For each reservoir, the apparant formation water resistivity and its evolution of each measurement point are calculated separately, it will be each
Measurement point is ranked up from small to large according to its apparant formation water resistivity evolution, calculates the accumulative frequency of each measurement point after sequence
Rate；
Step 3：For each reservoir, the cumulative frequency based on each measurement point and its corresponding apparant formation water resistivity
Evolution carries out linear fit under normal probability paper coordinate system, obtains intercept A and slope B corresponding to linear fit；
Step 4：Average pore and linear fit based on each reservoir are as a result, establish flow net model cross plot
Version, the wherein product of intercept A and slope B of the ordinate of flow net model crossplot corresponding to the linear fit
It determines, abscissa determines according to average pore；
Step 5：Based on the fluid properties corresponding to each reservoir, tool is divided on the flow net model crossplot
There is the region of different fluid property；
Step 6：For the reservoir to be identified in the region to be measured, repeating said steps 1-3, and according to reservoir to be identified
Average pore and linear fit as a result, determining the stream of the reservoir to be identified by the flow net model crossplot
Volume property.
Preferably, apparant formation water resistivity Rwa is calculated according to following formula (1)：
Rwa=RT/PORm (1)
Wherein, RT indicates that deep resistivity, POR indicate that porosity, m indicate region empirical value.
Preferably, m=2.
Preferably, the area with different fluid property is divided on the flow net model crossplot by line of demarcation
Domain.
Preferably, the reservoir to be identified in the region to be measured, repeating said steps 1-3 include：
Multiple measurement points are set in the reservoir to be identified, obtain the deep resistivity and porosity of each measurement point；
The apparant formation water resistivity and its evolution for calculating separately each measurement point of the reservoir to be identified, by each survey
Amount point is ranked up from small to large according to its apparant formation water resistivity evolution, calculates the cumulative frequency of each measurement point after sequence；
The cumulative frequency and its corresponding apparant formation water resistivity of each measurement point based on the reservoir to be identified are opened
Side carries out linear fit under normal probability paper coordinate system, obtains intercept and slope corresponding to linear fit.
Preferably, the ordinate of the flow net model crossplot corresponds to the intercept corresponding to the linear fit
The A and product A*B of the slope B or common logarithm lg (A*B) of the product.
Preferably, the abscissa of the flow net model crossplot corresponds to the average pore or described flat
The common logarithm of equal porosity.
Preferably, average pore and the linear fit according to reservoir to be identified is as a result, pass through the fluid properties
Identification crossplot determines that the fluid properties of the reservoir to be identified include：
The product of intercept and slope corresponding to the average pore of the reservoir to be identified and linear fit, in institute
It states and is projected on flow net model crossplot, so that it is determined that the fluid properties of the reservoir to be identified.
Compared with prior art, the beneficial effects of the present invention are using Logging Curves, using normal distribution method as base
Plinth establishes flow net model cross plot, improves complicated reservoirs fluid properties well logging discrimination precision.
The present invention is determines that properties of fluid in bearing stratum provides effective means, the ginseng used in method using Conventional Logs
Number can be obtained by Conventional Logs, have very strong operability and wide applicability, and effectively increase reservoir stream
Volume property logging evaluation precision has great practicality in the complicated reservoirs exploration and development such as carbonate rock, volcanic rock, tight sand
Value.
The method of the present invention has other characteristics and advantages, these characteristics and advantages from the attached drawing being incorporated herein and with
Will be apparent in specific embodiment afterwards, or by the attached drawing and subsequent specific embodiment being incorporated herein into
Row statement in detail, these the drawings and specific embodiments are used together to explain the specific principle of the present invention.
Description of the drawings
Exemplary embodiment of the present is described in more detail in conjunction with the accompanying drawings, of the invention is above-mentioned and other
Purpose, feature and advantage will be apparent.
Fig. 1 shows the method flow diagram of determination properties of fluid in bearing stratum accoding to exemplary embodiment；
Fig. 2 shows the flow net model crossplots in exemplary embodiment；
Fig. 3 shows the fluid properties reservoir log response figure to be identified in exemplary embodiment；
Fig. 4 shows the apparant formation water resistivity evolution of the fluid properties reservoir to be identified in exemplary embodiment and its tires out
Count the result of calculation and its Linear Fit Chart of frequency；
Fig. 5 shows the fluid properties reservoir differentiation figure to be identified in exemplary embodiment.
Specific implementation mode
The present invention is more fully described below with reference to accompanying drawings.Although showing the preferred embodiment of the present invention in attached drawing,
However, it is to be appreciated that may be realized in various forms the present invention without should be limited by embodiments set forth here.On the contrary, providing
These embodiments are of the invention more thorough and complete in order to make, and can will fully convey the scope of the invention to ability
The technical staff in domain.
The method of determining properties of fluid in bearing stratum according to an exemplary embodiment of the present invention mainly includes the following steps that：
Step 1：The multiple reservoirs for selecting known fluid property in region to be measured, are arranged multiple surveys in each reservoir respectively
Point is measured, the deep resistivity and porosity of each measurement point are obtained
It selects to have already passed through multiple reservoirs that formation testing or production are verified, the fluidity of the reservoir selected in this way in region to be measured
Matter is known.Multiple measurement points are set in each reservoir, obtain the deep resistivity and porosity of each measurement point.
Step 2：For each reservoir, the apparant formation water resistivity and its evolution of each measurement point are calculated separately, it will be each
Measurement point is ranked up from small to large according to its apparant formation water resistivity evolution, calculates the cumulative frequency of each measurement point after sequence
Wherein it is possible to calculate apparant formation water resistivity Rwa according to following formula (1)：
Rwa=RT/PORm (1)
Wherein, RT indicates that deep resistivity, POR indicate that porosity, m indicate region empirical value, generally take 2.
It is calculated after the apparant formation water resistivity Rwa of each measurement point, you can obtain the apparent reservoir water of the measurement point
Resistivity evolution.Then, each measurement point is ranked up from small to large according to its apparant formation water resistivity evolution, calculates sequence
The cumulative frequency of each measurement point afterwards.The cumulative frequency of measurement point refers to opening each measurement point according to its apparant formation water resistivity
After side is ranked up from small to large, in the measurement point sequence obtained, before the measurement point (including the measurement point exists
It is interior) measurement point quantity account for the percentage of overall measurement point quantity.The definition of cumulative frequency and its computational methods are showing for this field
There is technology, details are not described herein.
Step 3：For each reservoir, based on the cumulative frequency of each measurement point in the reservoir and its corresponding stratum is regarded
Water resistance rate evolution carries out linear fit under normal probability paper coordinate system, obtains intercept A and slope B corresponding to linear fit
For each reservoir, cumulative frequency and its corresponding apparent reservoir water resistance based on each measurement point in the reservoir
Rate evolution carries out linear fit under normal probability paper coordinate system, and the wherein abscissa of normal probability paper coordinate system indicates the tired of measurement point
The normal probability paper of frequency is counted, ordinate indicates the apparant formation water resistivity evolution of measurement point.By linear fit, can obtain with
Lower relational expression (2)：
Rwa1/2=B*f (F)+A (2)
Wherein, F indicates that cumulative frequency, f indicate normal probability function, Rwa1/2Indicate apparant formation water resistivity evolution, A tables
Intercept corresponding to linear fitting, B indicate the slope corresponding to linear fit.
Can be that each reservoir establishes a linear relation as shown in relational expression (2) by this step.
Step 4：Average pore and linear fit based on each reservoir are as a result, establish flow net model cross plot
Version, the product of wherein intercept A of the ordinate of flow net model crossplot corresponding to linear fit and slope B is come really
Fixed, abscissa is determined according to average pore.
In step 1, multiple measurement points are had chosen in each reservoir, and obtain the deep resistivity and hole of measurement point
Degree, the average value of the porosity of average pore, that is, each measurement point of reservoir.In this step, being averaged based on each reservoir
Porosity and the linear fit that obtains in step 3 are as a result, establish flow net model crossplot, flow net model intersection
The product of the ordinate of the plate intercept A corresponding to linear fit and slope B determines that abscissa is according to average pore
To determine.Under normal circumstances, the ordinate of flow net model crossplot correspond to linear fit corresponding to intercept A with tiltedly
The product A*B of the rate B or common logarithm lg (A*B) of the product, the abscissa of flow net model crossplot, which corresponds to, puts down
The common logarithm of equal porosity or average pore, those skilled in the art can select vertical accordingly sit according to actual needs
Mark and abscissa.
Step 5：Based on the fluid properties corresponding to each reservoir, being divided on flow net model crossplot has not
With the region of fluid properties
Due to the fluid properties of known each reservoir, can flowed based on the fluid properties corresponding to each reservoir
Volume property, which identifies, divides the region with different fluid property on crossplot, particularly, can be divided by line of demarcation has
The region of different fluid property.
Step 6：For the reservoir to be identified in region to be measured, step 1-3 is repeated, and according to the average hole of reservoir to be identified
Porosity and linear fit are as a result, determine the fluid properties of reservoir to be identified by flow net model crossplot.
For the reservoir to be identified in region to be measured, according to the method described in above step 1-3, first in reservoir to be identified
The middle multiple measurement points of setting, obtain the deep resistivity and porosity of each measurement point；Then reservoir to be identified is calculated separately
The apparant formation water resistivity and its evolution of each measurement point, by each measurement point according to its apparant formation water resistivity evolution from small
To being ranked up greatly, the cumulative frequency of each measurement point after sequence is calculated；Next each measurement point based on reservoir to be identified
Cumulative frequency and its corresponding apparant formation water resistivity evolution carry out linear fit under normal probability paper coordinate system, obtain line
Property the corresponding intercept of fitting and slope.
According to the average pore (average value of the porosity of i.e. each measurement point) and linear fit result of reservoir to be identified
(i.e. the product of intercept and slope), is projected on flow net model crossplot, you can determines the stream of reservoir to be identified
Volume property.
Example 1:
Carry out the logging evaluation of fluid properties for certain oil field carbonate rock fractured cave type reservoir using the above method, it is specific to walk
It is rapid as follows：
Step 1：For the well that the oil field has produced, the carbonate rock fractured cave type reservoir with oil reservoir and water layer conclusion is selected
Multiple measurement points are respectively set in 1-27 in each reservoir, obtain the deep resistivity (RT) and porosity of each measurement point
(POR)。
Secondary series and the third row of table 1 show average deep resistivity RD (each measurement points i.e. in reservoir of reservoir 1-27
The average value of deep resistivity) and average porosity value (i.e. the average value of the porosity of each measurement point in reservoir).
1 sample data statistical form of table
Step 2：Calculated separately according to following formula (3) each measurement point of each reservoir apparant formation water resistivity and its
Each measurement point is ranked up by evolution from small to large according to its apparant formation water resistivity evolution, is each measured after calculating sequence
The cumulative frequency of point：
Rwa=RT/POR2 (3)
Step 3：For each reservoir, the cumulative frequency based on each measurement point and its corresponding apparant formation water resistivity
Evolution carries out linear fit under normal probability paper coordinate system, obtains intercept and slope corresponding to linear fit.Reservoir 1-27's
Shown in the 4th row and the 5th row of intercept and slope corresponding to linear fit such as table 1, the of the product such as table 1 of intercept and slope
Shown in six row.
Step 4：Average pore and linear fit based on each reservoir are as a result, establish flow net model cross plot
Version, the wherein ordinate of flow net model crossplot are common pair of the corresponding intercept of linear fit and the product of slope
Number, abscissa are the common logarithm of average pore, as shown in Figure 2.In Fig. 2, each reservoir corresponds to a data point, data
The abscissa of point is the common logarithm of the average pore of the reservoir, and ordinate is the intercept corresponding to the linear fit of the reservoir
With the common logarithm of the product of slope, due to the fluid properties of known each reservoir, in fig. 2 with data point of different shapes
Indicate that the reservoir corresponding to different fluid property, wherein triangular data points indicate the reservoir corresponding to water layer, square number evidence
Point indicates the reservoir corresponding to oil reservoir.
Step 5：Based on the fluid properties corresponding to each reservoir, being divided on flow net model crossplot has not
With the region of fluid properties.As shown in Fig. 2, dividing the region with different fluid property, line of demarcation upper right side by line of demarcation
For oil reservoir, line of demarcation lower left is water layer.
Step 6：For the new well reservoir (Fig. 3) of properties of fluid in bearing stratum to be identified, multiple measurements are set in reservoir first
Point, reads the deep resistivity and porosity of each measurement point, then calculate separately each measurement point apparant formation water resistivity and
Each measurement point is ranked up by its evolution from small to large according to its apparant formation water resistivity evolution, is each surveyed after calculating sequence
Measure the cumulative frequency of point；It is then based on cumulative frequency and its corresponding the apparent reservoir water electricity of each measurement point in reservoir to be identified
Resistance rate evolution carries out linear fit under normal probability paper coordinate system, obtains intercept and slope corresponding to linear fit.Fig. 4 is shown
The apparant formation water resistivity evolution of each measurement point and its result of calculation of cumulative frequency and linear fit as a result, in Fig. 4
In, abscissa indicates that the normal probability paper of cumulative frequency, ordinate indicate apparant formation water resistivity evolution.
The product of intercept and slope corresponding to the average pore of new well reservoir and linear fit, in fluid properties
It is projected on identification crossplot, it can quick recognition using the line of demarcation for the different fluid Properties Area distinguished on cross plot
The fluid properties of new well reservoir.In this example, the data point corresponding to the reservoir to be identified is (1.798,0.0240), falls and is dividing
The upper right side (as shown in Figure 5) in boundary line, i.e., in oil reservoir area, therefore it is oil reservoir that identification conclusion, which is the new well reservoir, subsequent production
Conclusion proves reservoir oil-producing 171t/d, does not produce water, and recognition result is consistent with production conclusion.
The embodiment of the present invention is described above, above description is exemplary, and non-exclusive, and also not
It is limited to disclosed each embodiment.Without departing from the scope and spirit of illustrated each embodiment, for this technology
Many modifications and changes will be apparent from for the those of ordinary skill in field.The selection of term used herein, it is intended to
Best explain the principle, practical application or the improvement to the technology in market of each embodiment, or make the art its
Its those of ordinary skill can understand each embodiment disclosed herein.
Claims (8)
1. a kind of method of determining properties of fluid in bearing stratum, including：
Step 1：The multiple reservoirs for selecting known fluid property in region to be measured, are arranged multiple measurements in each reservoir respectively
Point obtains the deep resistivity and porosity of each measurement point；
Step 2：For each reservoir, the apparant formation water resistivity and its evolution of each measurement point are calculated separately, by each measurement
Point is ranked up from small to large according to its apparant formation water resistivity evolution, calculates the cumulative frequency of each measurement point after sequence；
Step 3：For each reservoir, the cumulative frequency based on each measurement point and its corresponding apparant formation water resistivity evolution
Linear fit is carried out under normal probability paper coordinate system, obtains intercept A and slope B corresponding to linear fit；
Step 4：Average pore and linear fit based on each reservoir as a result, establish flow net model crossplot,
The product of intercept A of the ordinate of middle flow net model crossplot corresponding to the linear fit and slope B is come really
Fixed, abscissa is determined according to average pore；
Step 5：Based on the fluid properties corresponding to each reservoir, being divided on the flow net model crossplot has not
With the region of fluid properties；
Step 6：For the reservoir to be identified in the region to be measured, repeating said steps 1-3, and putting down according to reservoir to be identified
Equal porosity and linear fit are as a result, determine the fluidity of the reservoir to be identified by the flow net model crossplot
Matter.
2. the method for determining properties of fluid in bearing stratum according to claim 1, wherein calculated according to following formula (1) and regard ground
Layer water resistance rate Rwa：
Rwa=RT/PORm (1)
Wherein, RT indicates that deep resistivity, POR indicate that porosity, m indicate region empirical value.
3. the method for determining properties of fluid in bearing stratum according to claim 2, wherein m=2.
4. the method for determining properties of fluid in bearing stratum according to claim 1, wherein by line of demarcation in the fluid properties
It identifies and divides the region with different fluid property on crossplot.
5. the method for determining properties of fluid in bearing stratum according to claim 1, wherein described in the region to be measured
Reservoir to be identified, repeating said steps 1-3 include：
Multiple measurement points are set in the reservoir to be identified, obtain the deep resistivity and porosity of each measurement point；
The apparant formation water resistivity and its evolution for calculating separately each measurement point of the reservoir to be identified, by each measurement point
It is ranked up from small to large according to its apparant formation water resistivity evolution, calculates the cumulative frequency of each measurement point after sequence；
The cumulative frequency of each measurement point based on the reservoir to be identified and its corresponding apparant formation water resistivity evolution exist
Linear fit is carried out under normal probability paper coordinate system, obtains intercept and slope corresponding to linear fit.
6. the method for determining properties of fluid in bearing stratum according to claim 1, wherein the flow net model crossplot
Ordinate correspond to intercept A and the product A*B of slope B or the common logarithm of the product corresponding to the linear fit
lg(A*B)。
7. the method for determining properties of fluid in bearing stratum according to claim 1, wherein the flow net model crossplot
Abscissa correspond to the common logarithm of the average pore or the average pore.
8. the method for determining properties of fluid in bearing stratum according to claim 1, wherein being averaged according to reservoir to be identified
Porosity and linear fit are as a result, determine the fluid properties of the reservoir to be identified by the flow net model crossplot
Including：
The product of intercept and slope corresponding to the average pore of the reservoir to be identified and linear fit, in the stream
It is projected on volume property identification crossplot, so that it is determined that the fluid properties of the reservoir to be identified.
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| CN114046145A (en) * | 2021-11-26 | 2022-02-15 | 中国石油大学(北京) | Reservoir fluid identification and saturation determination method and device |
| CN115234216A (en) * | 2022-05-25 | 2022-10-25 | 东营市永昇能源科技有限责任公司 | Method for establishing logging identification layout and application thereof |
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