CN105604546B - Quantitative classification method for dual-medium carbonate reservoir - Google Patents
Quantitative classification method for dual-medium carbonate reservoir Download PDFInfo
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
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Abstract
The invention provides a quantitative classification method for a dual-medium carbonate reservoir. The method comprises the following steps: 1) obtaining the matrix porosity, matrix permeability, fracture porosity and fracture permeability of a reservoir to be classified; the method comprises the following steps of (1) well bore radius and skin coefficient of a research well in which a reservoir to be classified is located, solubility of natural gas in formation water in the well, formation pressure in the well and formation temperature; the lower limit of the porosity and the lower limit of the permeability of the matrix of a research area where the reservoir to be classified is located; 2) obtaining the formation water compressibility of a research well, the matrix system rock effective compressibility of a reservoir to be classified and the fracture system rock effective compressibility; 3) acquiring a dimensionless series flow coefficient and a dimensionless shaft storage coefficient of a reservoir to be classified; 4) and determining the type of the reservoir to be classified according to the obtained parameters. The technical scheme provided by the invention can determine the type of the reservoir through the result of well logging interpretation, and is simple and convenient to operate.
Description
Technical field
The present invention relates to a kind of Quantitative Classification Methods of dual media carbonate reservoir, belong to the exploitation in oil development
Geology and reservoir engineering field.
Background technology
Compared with clastic rock, carbonate reservoir has anisotropism strong, and reservoir space type is various (matrix pores, molten
Borrosion hole hole, crack, microcrack) the characteristics of.The evaluation of classification of carbonate reservoir at present, there are many divide for the difference based on emphasis
Class scheme, but largely classified based on coring and thin section analysis data, or surveyed using Electrical imaging and nuclear-magnetism
Well data is classified：
Article " well logging recognition and evaluation of classification-of carbonate rock Complicated Pore Structures are by taking the stratum H of Middle East oil field as an example "
(Ni Guohui, Guo Haifeng, Xu Xing, yellow big qin petroleum gases journal (Jianghan Petroleum College's journal) .2014,36 (1):60-65)
Comprehensive analysis is carried out in terms of physical property characteristic, capillary pressure curve feature, Petrographic Features three, extracts reservoir properties and hole knot
The characteristic parameter of structure, qualitative division three classes reservoir, is combined with Electrical imaging and nuclear magnetic resonance log, establishes Reservoir type well logging
Plate is identified, but the plate is built upon on the basis of Electrical imaging and nuclear magnetic resonance log, for only having the oil field of conventional logging
Or individual well, it can not promote and apply.
Article " carbonate reservoir pore structure evaluation method " (Guo Zhenhua, Li Guanghui, Wu Lei, Li Xuren, Han Guiqin,
Jiang Ying brightness petroleum journals .2011,32 (3):459-465) according to reservoir properties composite index Z, (permeability divided by porosity are opened
Side) and capillary in duty pressure, carbonate reservoir is divided into four ranks, but for the list of non-coring or non-pressure measurement mercury
Well can not obtain duty pressure in capillary.
Article " carbonate porosity sorting technique the summary " (Inner Mongol Li Lin, Zhang Xuefeng petrochemical industry .2009 (8)：51-
54) it is as follows to disclose current CLASSIFICATION OF CARBONATE ROCKS main method：By matrix structure and pore size classification (including intergranular pore,
Fenestrule, masking aperture, intracrystalline pore, Growh framework hole, mould pore, crack, lapies, dissolution pore, solution cavity, dust hole, bores at intragranular hole
Hole, burrow hole, shrinkage hole), packet thatch, the hole of the propositions such as iron army, hole, seam categorizing system [including hole (megapore, coarse porosity, in
Hole, pinhole, micropore, hidden hole), hole (cave, hole gap), seam it is (huge seam, big seam, extra wide seam, wide seam, medium seam, narrow
Seam, slit, ultra micro seam)]；The above method is all the classification carried out from core wafer analysis foundation, but for no coring well
It can not promote and apply.
(Lee passes bright lithologic deposits .2008,20 (4) to article " comparison and analysis of two kinds of dual medias ":128-131)
In disclose utilize the qualitative difference fracture pore type reservoir of well-test curve form and production decline rule and fractured-porous reservoir type storage
Layer, but quantitative does not divide the method or formula of Reservoir type.
For overseas oil field, coring well, imaging and Nuclear Magnetic Resonance Logging are limited, it is difficult to deduce the institute in research area
There is well.
Therefore it provides a kind of Quantitative Classification Method of convenient and reliable dual media carbonate reservoir becomes this field urgently
One of problem to be solved.
Invention content
In order to solve the above technical problems, quantifying the purpose of the present invention is to provide a kind of dual media carbonate reservoir
Sorting technique, this method can carry out the division of Types of Carbonate Reservoir according to the result of well log interpretation, convenient and efficient, and
Test result is accurate and reliable.
In order to achieve the above objectives, the present invention provides a kind of Quantitative Classification Method of dual media carbonate reservoir,
Include the following steps：
Step 1: obtaining the parameter for the reservoir for needing to carry out quantitative classification, the parameter includes：
The matrix porosity Φ of the reservoir for needing to carry out quantitative classificationm, matrix permeability Km, fracture porosity ΦfWith
Fracture permeabgility Kf；
The wellbore radius r for needing research well where carrying out the reservoir of quantitative classificationw, skin factor S, natural gas in well
Solubility R in water floodingsw, strata pressure P and formation temperature T in well；
The lower limit Cutoff of the matrix porosity for needing to carry out the reservoir place research area of quantitative classificationporAnd matrix
The lower limit Cutoff of permeabilityperm；
Step 2: according to the parameter that step 1 obtains, calculate separately to obtain the water flooding compressed coefficient C of the research wellw、
The matrix system rock effective compressibility C of the reservoir for needing to carry out quantitative classificationf.mAnd Fracture System rock is effectively compressed
Coefficient Cf.f；
Step 3: utilizing the C in step 2w、Cf.m、Cf.f, calculate separately to obtain the storage for needing to carry out quantitative classification
The zero dimension crossfire coefficient ω and zero dimension bottom-hole storage coefficient C of layerD；
Step 4: the C that the parameter obtained using step 1, step 2 are obtainedw、Cf.m、Cf.f, step 3 obtained ω, CD,
Determine the type for the reservoir for needing to carry out quantitative classification.
In the above-mentioned methods, it is preferable that in step 4, determine the type belonging to the reservoir for needing to carry out quantitative classification
When, the criteria for classifying between different type reservoir is：
Work as Φm<Cutoffpor, and Kf+Km≤CutoffpermWhen, the reservoir for needing to carry out quantitative classification is densification
Layer；
Work as Φm<Cutoffpor, and Kf+Km>CutoffpermWhen, the reservoir for needing to carry out quantitative classification is slit formation
Reservoir；
Work as Φm≥Cutoffpor, andWhen, the reservoir for needing to carry out quantitative classification is pore type
Reservoir；
Work as Φm≥Cutoffpor, andAnd When, the reservoir for needing to carry out quantitative classification is crack hole
Gap type reservoir；
Work as Φm≥Cutoffpor, whileWhen, the reservoir for needing to carry out quantitative classification
For hole crack elimination.
In the above-mentioned methods, it is preferable that the porosity reservoir is characterized as：Matrix system for oil storage space and oozes simultaneously
Circulation road, and pressure build-up test shows single hole feature；The hole crack elimination is characterized as：Matrix system is main
Oil storage space (oil referred in stratum largely preserves inside matrix system), at the same time, matrix system and Fracture System are equal
For seepage channel, and pressure build-up test shows single hole feature or based on single hole feature, there are fraction diplopore features；
The fracture pore type reservoir is characterized as：Matrix system is oil storage space, and Fracture System is seepage channel, pressure build-up test
Show diplopore feature；The crack elimination is characterized as：Fracture System is oil storage space and seepage channel, pressure recovery simultaneously
Well testing shows single hole feature；The compacted zone is characterized as：Stratum is fine and close, and matrix system and Fracture System cannot be that oil storage is empty
Between and seepage channel；The division of Reservoir type is the basis of carbonate reservoir Geologic modeling and numerical simulation, these inhomogeneities
The reservoir of type is obtained according to the division of the seepage flow mechanism and well testing feature of reservoir.
In the above-mentioned methods, it is preferable that in step 2, the water flooding compressed coefficient CwCalculation formula be：
Cw=1.4504 × 10-4[(3.8546-1.9435×10-2P)+(-1.052×10-2+6.9183×10-5P)×
(1.8T+32)+(3.9267×10-5-1.2763×10-7P)×(1.8T+32)2]×(1.0+4.9974×10-2Rsw)。
In the above-mentioned methods, it is preferable that in step 2, the matrix system rock effective compressibility Cf.mCalculating
Formula is：
In the above-mentioned methods, it is preferable that in step 2, the Fracture System rock effective compressibility Cf.fCalculating
Formula：
In the above-mentioned methods, it is preferable that in step 3, the calculation formula of the zero dimension crossfire coefficient ω is：
In the above-mentioned methods, it is preferable that in step 3, the zero dimension bottom-hole storage coefficient CDCalculation formula be
In the above-mentioned methods, it is preferable that in step 1, the matrix porosity of the reservoir for needing to carry out quantitative classification
Φm, matrix permeability KmIt is to be explained to obtain by conventional logging；The fracture porosity of the reservoir for needing to carry out quantitative classification
Φf, fracture permeabgility KfIt is to be explained to obtain by imaging logging or conventional logging.
In the above-mentioned methods, it is preferable that in step 1, the wellbore radius r of the research wellw, skin factor S be by normal
It advises Pressure behaviour test or Pressure drawdown test dynamic tests acquisition；Dissolving of the natural gas in water flooding in the research well
Spend RswIt is to be analyzed to obtain by routine experiment；Strata pressure P, formation temperature T in the research well are by normal pressures and temperature
Degree measures acquisition；The matrix porosity lower limit Cutoff in the research areapor, matrix permeability lower limit CutoffpermIt is by taking
What the porosity and permeability relation curve and formation testing result of core well obtained.
In the above-mentioned methods, it is preferable that described to need to carry out between the reservoir of quantitative classification, research well, research area three
Position relationship be：Described that the reservoir for carrying out quantitative classification is needed to be located in the research well, the research well location is ground in described
Study carefully in area.
Beneficial effects of the present invention：
1) compared with prior art, the present invention not only provides the technical solution of quantification, and breaks previous be only capable of pair
The constraint that coring well or imaging logging data are classified can be applied to all non-coring wells and not survey imaging logging
All wells；
2) Quantitative Classification Method of dual media carbonate reservoir provided by the invention, it is simple to operate, according to survey
The result that well is explained can be carried out the classification of carbonate reservoir.
Description of the drawings
Fig. 1 is the result figure that core observation and description are carried out to 4335-4343m well sections in 8001 well of Kenkyak；
Fig. 2 is to carry out core observation to 4313.9-4314.5m and 4318.8-4319.5m well sections in 8016 well of Kenkyak
With the result figure of description；
Fig. 3 is the pressure fall-off test curve graph of 8016 well of Kenkyak；
Fig. 4 be to allow in Na Ruoer 2399A wells 3631-3633m, 3635.3-3635.7m and 3642-3643.3m well section into
The result figure of row core observation and description.
Specific implementation mode
In order to which technical characteristic, purpose and the advantageous effect to the present invention are more clearly understood, now to the skill of the present invention
Art scheme carry out it is described further below, but should not be understood as to the present invention can practical range restriction.
Embodiment 1
Present embodiments provide a kind of Quantitative Classification Method of reservoir.
The present embodiment is using 8001 wells under Kenkyak salt as research object, the matrix porosity lower limit Cutoff in the regionpor
It is 6%, quantitative classification is carried out to the Reservoir type of 4335-4343m well sections in the well.By 4335-4343 well sections with 0.1m or
The unit spacing of 0.125m is divided into several and fathoms, and can know after determining the Reservoir type each to fathom
The Reservoir type of 4335-4343 well sections.
Below by taking the 4335m that fathoms as an example, concrete operation step is as follows：
1) the matrix porosity Φ to fathom is obtained by conventional logging explanation respectivelym, matrix permeability Km；
The fracture porosity Φ to fathom is obtained by conventional logging explanation respectivelyf, fracture permeabgility Kf；
The wellbore radius r of 8001 wells is obtained by normal pressures dynamic test (or Pressure drawdown test dynamic is tested)w、
With skin factor S；
It is analyzed by routine experiment and obtains solubility R of the natural gas in water flooding in 8001 wellssw；
The strata pressure P and formation temperature T that obtain in 8001 wells are measured by normal pressures and temperature；
The matrix hole under Kenkyak salt is obtained by the porosity and permeability relation curve and formation testing result of coring well
Porosity lower limit Cutoffpor(6%) and matrix permeability lower limit Cutoffperm；
3) the solubility R according to the natural gas of above-mentioned acquisition in water floodingsw, strata pressure P and formation temperature T, calculate
Obtain the water flooding compressed coefficient C of 8001 wellsw[wherein：Cw=1.4504 × 10-4[(3.8546-1.9435×10-2P)+(-
1.052×10-2+6.9183×10-5P)×(1.8T+32)+(3.9267×10-5-1.2763×10-7P)×(1.8T+32)2]
×(1.0+4.9974×10-2Rsw)]；
According to the matrix porosity Φ of above-mentioned acquisitionm, the matrix system rock that the 4335m that fathoms is calculated effectively presses
Contracting coefficient Cf.m(wherein：)；
According to the fracture porosity Φ of above-mentioned acquisitionf, the Fracture System rock that the 4335m that fathoms is calculated effectively presses
Contracting coefficient Cf.f(wherein：)；
4) according to above-mentioned water flooding compressed coefficient Cw, matrix system rock effective compressibility Cf.mWith Fracture System rock
Effective compressibility Cf.f, the zero dimension crossfire coefficient ω and zero dimension bottom-hole storage coefficient C of the 4335m that fathoms is calculatedD
(wherein：)；
5) judge the Reservoir type of 4335m of fathoming：
The matrix porosity Φ to fathomm≥Cutoffpor, andIt can thus be appreciated that the measurement is deep
The Reservoir type of degree is porosity reservoir；
6) a pair of other fathom and carry out quantitative analysis according to the method described above, and result is：Other fathom full
Foot：Φm≥Cutoffpor, andCondition, be porosity reservoir；Thus 8001 wells under Kenkyak salt
The Reservoir type of middle 4335-4343m well sections is porosity reservoir.
To verify the above-mentioned quantitative point of correctness for carrying out method, to the rock core of the well section observe and describe that (result is such as
Shown in Fig. 1), it is porosity reservoir to find the well section really, shows that technical solution provided by the invention is correct feasible.
Embodiment 2
Present embodiments provide a kind of Quantitative Classification Method of reservoir.
The present embodiment is using 8016 wells under Kenkyak salt as research object, the matrix porosity lower limit Cutoff in the regionpor
It is 6%, quantitative classification is carried out to the Reservoir type of 4313.9-4314.5m and 4318.8-4319.5m well sections in the well respectively.Ginseng
According to embodiment 1 method respectively by 4313.9-4314.5m and 4308.8-4319.5m well sections between the unit of 0.1m or 0.125m
It fathoms away from several are divided into, then determines the Reservoir type each to fathom respectively.
As a result it is：It is satisfied by 4313.9-4314.5m fathoming with each of 4318.8-4319.5m well sections：
Φm≥Cutoffpor, andAnd Condition, be fracture pore type reservoir；It can thus be appreciated that agreeing
The Reservoir type of 4313.9-4314.5m and 4318.8-4319.5m well sections is fracture pore type in 8016 wells under Ji Yake salt
Reservoir.
To verify the above-mentioned quantitative point of correctness for carrying out method, the rock core of above-mentioned two well section is observed and described
(the results are shown in Figure 2) finds that above-mentioned two well section has a degree of microcrack to develop, and pressure fall-off test curve shows as dual
Dielectric attribute (as shown in Figure 3), is fracture pore type reservoir really, and surface technical solution provided by the invention is correct feasible
's.
Embodiment 3
Present embodiments provide a kind of Quantitative Classification Method of reservoir.
The present embodiment is to allow the oil fields Na Ruoer 2399A wells as research object, the matrix porosity lower limit in the region
CutoffporIt is 6%, respectively to allowing 3631-3633m, 3635.3-3635.7m and 3642- in the 2399A wells of the oil fields Na Ruoer
The Reservoir type of 3643.3m well sections carries out quantitative classification.Above three well section is quantified respectively with reference to the method for embodiment 1
Classification.
As a result it is：Each of above three well section, which fathoms, to be satisfied by：Φm≥Cutoffpor, and
AndCondition, be hole crack elimination；By
Allow the Reservoir type of 3631-3633m, 3635.3-3635.7m and 3642-3643.3m well section in Na Ruoer 2399A wells known to this
It is hole crack elimination.
To verify the above-mentioned quantitative point of correctness for carrying out method, the rock core of above three well section is observed and described
(the results are shown in Figure 4), it is found that the crack of above three well section is extremely developed, and is hole crack elimination, this hair of surface really
The technical solution of bright offer is correct feasible.
Claims (11)
1. a kind of Quantitative Classification Method of dual media carbonate reservoir comprising following steps：
Step 1: obtaining the parameter for the reservoir for needing to carry out quantitative classification, the parameter includes：
The matrix porosity Φ of the reservoir for needing to carry out quantitative classificationm, matrix permeability Km, fracture porosity ΦfThe crack and
Permeability Kf；
The wellbore radius r for needing research well where carrying out the reservoir of quantitative classificationw, skin factor S, in well natural gas on ground
Solubility R in layer watersw, strata pressure P and formation temperature T in well；
The lower limit Cutoff of the matrix porosity for needing to carry out the reservoir place research area of quantitative classificationporAnd matrix infiltration
The lower limit Cutoff of rateperm；
Step 2: according to the parameter that step 1 obtains, calculate separately to obtain the water flooding compressed coefficient C of the research wellw, it is described
Need the matrix system rock effective compressibility C of the reservoir of progress quantitative classificationf.mAnd Fracture System rock effective compressibility
Cf.f；
Step 3: utilizing the C in step 2w、Cf.m、Cf.f, calculate separately to obtain the nothing of the reservoir for needing to carry out quantitative classification
Dimension crossfire coefficient ω and zero dimension bottom-hole storage coefficient CD；
Step 4: the C that the parameter obtained using step 1, step 2 are obtainedw、Cf.m、Cf.f, step 3 obtained ω, CD, determine
Need the type of the reservoir of progress quantitative classification.
2. according to the method described in claim 1, wherein：In step 4, determine belonging to the reservoir for needing to carry out quantitative classification
Type when, the criteria for classifying between different type reservoir is：
Work as Φm<Cutoffpor, and Kf+Km≤CutoffpermWhen, the reservoir for needing to carry out quantitative classification is compacted zone；
Work as Φm<Cutoffpor, and Kf+Km>CutoffpermWhen, the reservoir for needing to carry out quantitative classification is crack elimination；
Work as Φm≥Cutoffpor, andWhen, the reservoir for needing to carry out quantitative classification is porosity reservoir；
Work as Φm≥Cutoffpor, andAnd When, the reservoir for needing to carry out quantitative classification is crack hole
Gap type reservoir；
Work as Φm≥Cutoffpor, andAndWhen, the reservoir for needing to carry out quantitative classification
For hole crack elimination.
3. according to the method described in claim 2, wherein：
The porosity reservoir is characterized as：Matrix system is simultaneously oil storage space and seepage channel, and pressure build-up test
Show single hole feature；
The hole crack elimination is characterized as：Matrix system is main oil storage space, at the same time, matrix system and crack
System is seepage channel, and pressure build-up test shows single hole feature；
The fracture pore type reservoir is characterized as：Matrix system is oil storage space, and Fracture System is seepage channel, pressure recovery
Well testing shows diplopore feature；
The crack elimination is characterized as：Fracture System is oil storage space and seepage channel simultaneously, and pressure build-up test is shown
Single hole feature；
The compacted zone is characterized as：Stratum is fine and close, and matrix system and Fracture System cannot be oil storage space and seepage channel.
4. according to the method described in claim 1, wherein：In step 2, the water flooding compressed coefficient CwCalculation formula be
Cw=1.4504 × 10-4[(3.8546-1.9435×10-2P)+(-1.052×10-2+6.9183×10-5P)×(1.8T+
32)+(3.9267×10-5-1.2763×10-7P)×(1.8T+32)2]×(1.0+4.9974×10-2Rsw)。
5. according to the method described in claim 1, wherein：In step 2, the matrix system rock effective compressibility Cf.m
Calculation formula be
6. according to the method described in claim 1, wherein：In step 2, the Fracture System rock effective compressibility Cf.f
Calculation formula
7. according to claim 1-6 any one of them methods, wherein：In step 3, the zero dimension crossfire coefficient ω's
Calculation formula is
8. according to claim 1-6 any one of them methods, wherein：In step 3, the zero dimension bottom-hole storage coefficient CD
Calculation formula be
9. according to the method described in claim 7, wherein：In step 3, the zero dimension bottom-hole storage coefficient CDCalculating it is public
Formula is
10. according to the method described in claim 1, wherein：In step 1,
The matrix porosity Φ of the reservoir for needing to carry out quantitative classificationm, matrix permeability KmIt is to be explained to obtain by conventional logging
's；
The fracture porosity Φ of the reservoir for needing to carry out quantitative classificationf, fracture permeabgility KfIt is by imaging logging or conventional survey
Well explains acquisition；
The wellbore radius r of the research wellw, skin factor S be by Pressure behaviour test or Pressure drawdown test dynamic test obtain
's；
Solubility R of the natural gas in water flooding in the research wellswIt is to be analyzed to obtain by routine experiment；
Strata pressure P, formation temperature T in the research well are to be measured to obtain by normal pressures and temperature；
The matrix porosity lower limit Cutoff in the research areapor, matrix permeability lower limit CutoffpermIt is by the hole of coring well
What degree and permeability relation curve and formation testing result obtained.
11. according to the method described in claim 1, wherein：It is described to need to carry out the reservoir of quantitative classification, research well, research area
Position relationship between three is：
Described that the reservoir for carrying out quantitative classification is needed to be located in the research well, the research well location is in the research area.
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| CN106837321A (en) * | 2017-01-25 | 2017-06-13 | 中国石油大学(北京) | A kind of method for recovering natural gas subsurface occurrence |
| CN107704646B (en) * | 2017-08-11 | 2021-06-01 | 中国石油天然气股份有限公司 | Modeling method after compact reservoir volume modification |
| CN108088779B (en) * | 2017-12-27 | 2020-02-07 | 中国石油大学(华东) | Reservoir space classification method for compact reservoir and conventional reservoir |
| CN110486004B (en) * | 2018-05-14 | 2022-05-10 | 中国石油天然气股份有限公司 | Method and device for identifying water flow dominant channel of sandstone reservoir |
| CN108843300B (en) * | 2018-06-25 | 2022-03-01 | 中国石油天然气股份有限公司 | Method and device for determining type of main flow channel in complex porous medium |
| CN111239372B (en) * | 2020-03-12 | 2022-02-15 | 西安石油大学 | Carbonate rock pore structure classification method based on overburden seepage experiment |
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