CN105628580A - Reservoir false crack identification and physical property correction method - Google Patents
Reservoir false crack identification and physical property correction method Download PDFInfo
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- 230000000704 physical effect Effects 0.000 title claims abstract description 27
- 238000012937 correction Methods 0.000 title abstract description 24
- 238000000034 method Methods 0.000 title abstract description 19
- 230000035699 permeability Effects 0.000 claims abstract description 51
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 claims abstract description 44
- 239000011435 rock Substances 0.000 claims abstract description 43
- 238000005266 casting Methods 0.000 claims abstract description 25
- 229910052753 mercury Inorganic materials 0.000 claims abstract description 22
- 238000002347 injection Methods 0.000 claims abstract description 7
- 239000007924 injection Substances 0.000 claims abstract description 7
- 238000012360 testing method Methods 0.000 claims description 17
- 238000003703 image analysis method Methods 0.000 claims description 7
- 238000011160 research Methods 0.000 claims description 3
- 230000000694 effects Effects 0.000 abstract description 3
- 238000013441 quality evaluation Methods 0.000 abstract description 2
- 238000005553 drilling Methods 0.000 abstract 1
- 238000011161 development Methods 0.000 description 12
- 208000010392 Bone Fractures Diseases 0.000 description 10
- 206010017076 Fracture Diseases 0.000 description 10
- 238000009826 distribution Methods 0.000 description 8
- 239000004568 cement Substances 0.000 description 5
- 238000010586 diagram Methods 0.000 description 5
- 238000004458 analytical method Methods 0.000 description 4
- 230000015572 biosynthetic process Effects 0.000 description 4
- 229910001711 laumontite Inorganic materials 0.000 description 4
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 3
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 3
- 239000008187 granular material Substances 0.000 description 3
- 239000006185 dispersion Substances 0.000 description 2
- 230000003628 erosive effect Effects 0.000 description 2
- 230000012010 growth Effects 0.000 description 2
- 231100000481 chemical toxicant Toxicity 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000005429 filling process Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000006396 nitration reaction Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000004310 photopic vision Effects 0.000 description 1
- 238000004445 quantitative analysis Methods 0.000 description 1
- 239000003440 toxic substance Substances 0.000 description 1
- 230000001131 transforming effect Effects 0.000 description 1
- 238000009966 trimming Methods 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
- 239000002023 wood Substances 0.000 description 1
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/088—Investigating volume, surface area, size or distribution of pores; Porosimetry
- G01N15/0886—Mercury porosimetry
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N2015/0813—Measuring intrusion, e.g. of mercury
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- General Health & Medical Sciences (AREA)
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- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
Abstract
The invention relates to a reservoir false crack identification and physical property correction method. According to the method, on the basis of identifying a true crack and a false crack by the utilization of a rock casting thin section; establishing a function relationship between mercury intrusion three-dimensional apparent porosity phi 3 and reservoir permeability K by the utilization of mercury injection data, and establishing a relationship between the mercury intrusion three-dimensional apparent porosity phi 3 and thin section two-dimensional apparent porosity phi 2 by the utilization of the mercury injection data as well as casting thin section data, a three-dimensional apparent aperture generated by the false crack is eliminated, and the effect of the false crack developing in a drilling rock core on rock sample gas logging porosity and gas logging permeability is eliminated. Compared with the prior art, as the three-dimensional apparent aperture generated by the false crack is eliminated, the porosity and permeability data distortion caused by the existence of the false crack is avoided, and the gas logging porosity and gas logging permeability results are accurate, the reservoir crack identification and physical property correction method can be used for reservoir quality evaluation.
Description
Technical field
The invention belongs to oil and gas exploration and development technique field, specifically, relate to a kind of reservoir baste identification and physical property bearing calibration.
Background technology
The gas gaging hole porosity of reservoir and perm-plug method are the most important parameters carrying out Effective Reservoirs evaluation in oil-gas bearing basin exploration and development, and whether it accurately directly affects oil-gas exploration and development plan implementation.
Turning the good wood river ,-Xin light area good two-stage nitration glutenite of group in Northwestern Margin of Junggar Basin is compact reservoir, but a large amount of growths due to laumontite cement, cause that drill cores is taking to the process on earth's surface from the degree of depth deep under ground more than 3500m, baste in rock core is caused to grow in a large number owing to temperature reduction, earth pressure release, formation water spilling, mechanical external force effect etc., laumontite and rock particles compositional difference shrink. The growth in false crack causes the increase of rock sample interstitial space and the extension of seepage channel, cause that the porosity and permeability that little rock sample analysis obtains is substantially higher, permeability value reaches tens even hundreds of mD, substantially it is not inconsistent with the extremely low feature of oozing of 0.005��0.05mD of reservoir formation testing production material explanation, the true physical property characteristic of the reservoir under formation condition can not be reflected, have a strong impact on the accuracy of evaluating reservoir, it is therefore necessary to be corrected such sample physical data for reservoir characteristic analysis.
For rock core is grown the reservoir having a large amount of false cracks, Xinjiang Oilfield Company adopts the method for low-pressure injection full-hole core-many confined pressures test permeability, 1 piece of full-hole core sample of new light 1 well has carried out the test of permeability when 1-6Mpa confined pressure, and this method can correct the false crack impact on permeability to a certain extent. But there is some deficiency following in this method:
(1) its impact on porosity can not be corrected.
(2), in filling process, by true crack filling together in reservoir, the accuracy of result is affected.
(3) utilizing such full-hole core Physical Property Analysis equipment to carry out rock sample Physical Property Analysis with high costs, relate to the use of the toxic chemical such as benzene, methanol in addition, danger coefficient is higher.
(4) subterranean well is cored is the most precious firsthand information, and low-pressure injection test needs a large amount of full-hole cores, sample broke is bigger, it is easy to cause waste, it is difficult to utilize the method to carry out large batch of rock sample physical property measurement.
Accordingly, it would be desirable to develop simple and feasible, easily operated physical property bearing calibration.
Summary of the invention
The present invention is directed to prior art above shortcomings, it is provided that a kind of reservoir baste identification and physical property bearing calibration, the method can eliminate the false crack grown in the drill cores impact on rock sample gas gaging hole porosity and perm-plug method effect effectively.
According to one embodiment of the invention, it is provided that a kind of reservoir baste identification and physical property bearing calibration, containing following steps:
Collection research district high-pressure mercury test data, sets up the aobvious porosity �� of pressure hydrargyrum three-dimensional according to high-pressure mercury data3 showFunctional relationship with reservoir permeability K.
According to the casting body flake data matched with high-pressure mercury test data, by image analysis method, the aobvious porosity �� of two dimension in quantitative statistics casting body flake2 show, the aobvious porosity �� of matching pressure hydrargyrum three-dimensional3 showPorosity �� aobvious with casting body flake two dimension2 showRelation.
According to Reservoir Microproperties, it is determined that the feature in true crack and false crack and recognition marks in casting body flake, utilize image analysis method, the quantitative statistics vacation crack two-dimentional porosity �� in casting body flake2 bastes, according to the aobvious porosity �� of pressure hydrargyrum three-dimensional3 showPorosity �� aobvious with casting body flake two dimension2 showRelation, quantitatively asks for false crack three-dimension hole porosity �� in rock3 bastes��
Utilize the reservoir three-dimensional total porosity �� of high-pressure mercury test dataAlwaysDeduct false crack three-dimension hole porosity �� in rock3 is false Seam, it is thus achieved that the three-dimensional true hole porosity �� of rockVery��
Utilize the aobvious porosity �� of three-dimensional of pressure hydrargyrum3 showDeduct false crack three-dimension hole porosity �� in rock3 bastes, it is thus achieved that the three-dimensional true aobvious porosity �� of rockAobvious true; Three-dimensional true aobvious porosity �� according to rockAobvious trueAnd the aobvious porosity �� of three-dimensional3 showWith the functional relationship of reservoir permeability K, ask for the true permeability K of rockVery��
In the reservoir baste identification and physical property bearing calibration of the above embodiment of the present invention offer, set up the aobvious porosity �� of pressure hydrargyrum three-dimensional according to high-pressure mercury data3 showWith the step of reservoir permeability K functional relationship it is: the contribution to permeability according to high-pressure mercury data characteristic and different scale hole, it is determined that aobvious hole and the critical point of micropore, calculates the aobvious porosity �� of three-dimensional of the rock sample of Mercury-injection test according to critical point3 showWith three-dimensional micropore porosity ��3 is micro-, the aobvious porosity �� of matching pressure hydrargyrum three-dimensional3 showFunctional relationship with reservoir permeability K.
In the reservoir baste identification and physical property bearing calibration of the above embodiment of the present invention offer, the contribution to permeability according to high-pressure mercury data characteristic and different scale hole, it is determined that permeability contribution is not less than 90% and size be not less than the minimum node hole of 0.25 ��m and shout the critical point that radius is aobvious hole and micropore.
In the reservoir baste identification and physical property bearing calibration of the above embodiment of the present invention offer, the aobvious porosity �� of pressure hydrargyrum three-dimensional3 showWith the functional relationship of reservoir permeability K it is:Wherein, A, B are constant.
In the reservoir baste identification and physical property bearing calibration of the above embodiment of the present invention offer, the aobvious porosity �� of pressure hydrargyrum three-dimensional3 showPorosity �� aobvious with casting body flake two dimension2 showRelation be: ��3 show=C* ��2 show+ D, wherein, C, D are constant.
Being about 0.1mm according to the distinguishable photopic vision of physics principle human eye from the minimal linear distance located, therefore when microscope amplifies 200 times, the minimal linear distance that human eye is differentiated is 0.5 ��m, and it is 0.25 ��m that the hole minimum aperture that namely can recognise that shouts radius. A kind of reservoir baste identification provided according to embodiments of the present invention and physical property bearing calibration, the method utilizes casting body flake to carry out the identification of hole and seam, in application process, it is possible to the aobvious hole and the micropore critical dimension that identify are not less than 0.25 ��m; The method is utilizing the true crack of rock casting body flake identification-vacation crack, is utilizing pressure hydrargyrum data to set up the aobvious porosity �� of pressure hydrargyrum three-dimensional3 showThe aobvious porosity �� of pressure hydrargyrum three-dimensional is set up with the functional relationship of reservoir permeability K, utilization pressure hydrargyrum data and casting body flake data3 showPorosity �� aobvious with thin slice two dimension2 showOn the basis of relation, reject the produced three-dimensional aobvious slit in false crack, eliminate the false crack grown in the drill cores impact on the rock sample gentle survey permeability result of gas gaging hole porosity. Compared with prior art, a kind of reservoir baste identification provided by the embodiment of the present invention and physical property bearing calibration carry out reservoir vacation crack identification and physical property correction, owing to eliminating three-dimensional aobvious slit produced by false crack, avoid false crack and there is the porosity and permeability data distortion caused, gas gaging hole porosity gentle survey permeability result is accurate, it is possible to for reservoir quality evaluation.
Accompanying drawing explanation
Fig. 1 is the flow chart of specific embodiment of the invention reservoir baste identification and physical property bearing calibration.
Fig. 2 a-f is the identification schematic diagram in dissimilar true crack and false crack in casting body flake.
Fig. 3 is Xinjiang Oilfield somewhere permeability in the specific embodiment of the invention-aobvious porosity transforming relationship figure.
Fig. 4 is the aobvious porosity of Xinjiang Oilfield somewhere three-dimensional porosity graph of a relation aobvious with two dimension in the specific embodiment of the invention.
Fig. 5 a is that in the specific embodiment of the invention, photo under 13 wells, 4088.82m petrographic thin section microscope is turned in Xinjiang Oilfield somewhere.
Fig. 5 b is that in the specific embodiment of the invention, baste identification figure in 13 wells, 4088.82m petrographic thin section is turned in Xinjiang Oilfield somewhere.
Fig. 5 c be in the specific embodiment of the invention Xinjiang Oilfield somewhere turn 13 wells, 4088.82m petrographic thin section identification baste after for utilizing the identification figure of baste content in image analysis method quantitative Analysis reservoir.
Fig. 6 a is the front distribution of porosity rectangular histogram of reservoir correction of vacation fracture development in Xinjiang Oilfield somewhere in the specific embodiment of the invention.
Fig. 6 b be vacation fracture development in Xinjiang Oilfield somewhere in the specific embodiment of the invention reservoir correction after porosity distribution histogram.
Fig. 6 c be vacation fracture development in Xinjiang Oilfield somewhere in the specific embodiment of the invention reservoir correction before and correction after porosity comparison diagram.
Fig. 7 a is the front Permeability Distribution rectangular histogram of reservoir correction of vacation fracture development in Xinjiang Oilfield somewhere in the specific embodiment of the invention.
Fig. 7 b be vacation fracture development in Xinjiang Oilfield somewhere in the specific embodiment of the invention reservoir correction after Permeability Distribution rectangular histogram.
Fig. 7 c be vacation fracture development in Xinjiang Oilfield somewhere in the specific embodiment of the invention reservoir correction before and correction after permeability comparison diagram.
The false crack of rule in figure, between F1, grain edges and laumontite cement; F2, granule internal fracture vacation crack; T1, cement erosion type vacation crack; T2, granule erosion type vacation crack; Really break inside T3, granule seam, rear glued thing filling; T4, pack grain break seam cement corrosion formed true crack.
Detailed description of the invention
Below in conjunction with the drawings and specific embodiments, the present invention is further illustrated.
For the laumontite cement gravel reservoir properties trimming process of Xinjiang Oilfield somewhere vacation fracture development, the specific embodiment of the present invention is described.
Fig. 1 is the flow chart of a kind of reservoir baste identification provided according to embodiments of the present invention and physical property bearing calibration, and this reservoir baste identification and physical property bearing calibration contain following steps:
Step 1: collection research district high-pressure mercury test data, the contribution to permeability according to high-pressure mercury data characteristic and different size hole, determine 0.293 ��m of boundary for aobvious hole and micropore, under this terminal conditions, show the hole contribution margin to permeability all more than 90%, and the reservoir of 87% shows the hole contribution margin to permeability more than 95%. Shout on the basis that radius is determined at critical hole, calculate the aobvious porosity �� of three-dimensional of the rock sample of Mercury-injection test3 showWith three-dimensional micropore porosity ��3 is micro-, and the aobvious porosity �� of matching pressure hydrargyrum three-dimensional3 showWith the functional relationship of reservoir permeability K, the aobvious porosity �� of pressure hydrargyrum three-dimensional3 showWith the functional relationship of reservoir permeability K it is:As it is shown on figure 3, R2Poor for this functional standard, R2=0.7311, its size represents the dispersion degree of data.
Step 2: according to the casting body flake data matched with high-pressure mercury test data, by image analysis method, the aobvious porosity �� of two dimension in quantitative statistics casting body flake2 show, the aobvious porosity �� of matching pressure hydrargyrum three-dimensional3 showPorosity �� aobvious with casting body flake two dimension2 showRelation, the aobvious porosity �� of pressure hydrargyrum three-dimensional3 showPorosity �� aobvious with casting body flake two dimension2 showRelation be: ��3 show=1.5343 ��2 show+ 0.3045; As shown in Figure 4, R2Poor for this functional standard, R2=0.8912, its size represents the dispersion degree of data.
Step 3: according to Reservoir Microproperties, it is determined that the feature in true crack and false crack and recognition marks in casting body flake, as in figure 2 it is shown, on this basis, utilizes image analysis method, the quantitative statistics vacation crack two-dimentional porosity �� in petrographic thin section2 bastes. As it is shown in figure 5, turn 13 wells, 4088.82m rock core for Xinjiang Oilfield somewhere, add up to obtain the two-dimentional porosity �� in false crack in rock core2 bastes=2.0%; As shown in Figure 4, according to equation ��3 show=1.5343 ��2 show+ 0.3045, quantitatively ask for false crack three-dimension hole porosity �� in this block rock3 bastes=3.34%. Table 1 is for turning parameter comparison table before and after 13 wells, the correction of 4088.82m rock core.
Table 1
Step 4: as shown in Table 1, utilizes the reservoir three-dimensional total porosity �� of high-pressure mercury test dataAlways=11.6% deducts false crack three-dimension hole porosity �� in rock3 bastes=3.34%, it is thus achieved that the three-dimensional true hole porosity �� of rockVery=8.26%.
Step 5: as shown in Table 1, utilizes the aobvious porosity �� of three-dimensional of pressure hydrargyrum3 show=3.9% deducts false crack three-dimension hole porosity �� in rock3 bastes=3.34%, it is thus achieved that the three-dimensional true aobvious porosity �� of rockAobvious true=0.56%; By the three-dimensional true aobvious porosity �� of rockAobvious true=0.56% substitutes into the aobvious porosity �� of three-dimensional3 showFunctional relationship with reservoir permeability KAs it is shown on figure 3, ask for the true permeability K of rockVery=0.12mD, compared with the rock permeability of 47.9mD before correction, after rectification, rock permeability more meets rock real features.
Fig. 6 a, 6b, 6c respectively Xinjiang Oilfield somewhere vacation fracture development reservoir correction before distribution of porosity rectangular histogram, correction after porosity distribution histogram, correction before and correction after porosity comparison diagram. Fig. 7 a, 7b, 7c respectively Xinjiang Oilfield somewhere vacation fracture development reservoir correction before Permeability Distribution rectangular histogram, correction after Permeability Distribution rectangular histogram, correction before and correction after permeability comparison diagram. Be can be seen that by Fig. 6 a-6c, Fig. 7 a-7c, the reservoir porosity after the inventive method correction is utilized to reduce about 2-4%, permeability is then substantially reduced, the background growing tight sandy gravel reservoir with this area's entirety is coincide, and the permeability after correction differs 1 order of magnitude with the formation fluid permeability (0.005-0.05mD) of formation testing, the ratio surveying permeability with perm-plug method and liquid is comparatively identical, and result is comparatively accurate.
Embodiment provided above is only with illustrating the present invention for convenience; not limiting the scope of the invention; at technical scheme category of the present invention, person of ordinary skill in the field is made various simple deformation and modification, should be included in above claim.
Claims (5)
1. a reservoir baste identification and physical property bearing calibration, it is characterised in that: containing following steps:
Collection research district high-pressure mercury test data, sets up the aobvious porosity of pressure hydrargyrum three-dimensional according to high-pressure mercury dataFunctional relationship with reservoir permeability K;
According to the casting body flake data matched with high-pressure mercury test data, by image analysis method, the aobvious porosity of two dimension in quantitative statistics casting body flakeThe aobvious porosity of matching pressure hydrargyrum three-dimensionalPorosity aobvious with casting body flake two dimensionRelation;
According to Reservoir Microproperties, it is determined that the feature in true crack and false crack and recognition marks in casting body flake, utilize image analysis method, the quantitative statistics vacation crack two-dimentional porosity in casting body flakeAccording to the aobvious porosity of pressure hydrargyrum three-dimensionalPorosity aobvious with casting body flake two dimensionRelation, quantitatively asks for false crack three-dimension hole porosity in rock
Utilize the reservoir three-dimensional total porosity �� of high-pressure mercury test dataAlwaysDeduct false crack three-dimension hole porosity in rockObtain the three-dimensional true hole porosity �� of rockVery;
Utilize the aobvious porosity of three-dimensional of pressure hydrargyrumDeduct false crack three-dimension hole porosity in rockObtain the three-dimensional true aobvious porosity �� of rockAobvious true; Three-dimensional true aobvious porosity �� according to rockAobvious trueAnd the aobvious porosity of three-dimensionalWith the functional relationship of reservoir permeability K, ask for the true permeability K of rockVery��
2. reservoir baste identification as claimed in claim 1 and physical property bearing calibration, it is characterised in that: set up the aobvious porosity of pressure hydrargyrum three-dimensional according to high-pressure mercury dataWith the step of reservoir permeability K functional relationship it is: the contribution to permeability according to high-pressure mercury data characteristic and different scale hole, it is determined that aobvious hole and the critical point of micropore, calculates the aobvious porosity of three-dimensional of the rock sample of Mercury-injection test according to critical pointWith three-dimensional micropore porosityThe aobvious porosity of matching pressure hydrargyrum three-dimensionalFunctional relationship with reservoir permeability K.
3. reservoir baste identification as claimed in claim 2 and physical property bearing calibration, it is characterized in that: the contribution to permeability according to high-pressure mercury data characteristic and different scale hole, it is determined that permeability contribution is not less than 90% and size be not less than the minimum node hole of 0.25 ��m and shout the critical point that radius is aobvious hole and micropore.
4. reservoir baste identification as described in claim 1 or 2 any one and physical property bearing calibration, it is characterised in that: the aobvious porosity of pressure hydrargyrum three-dimensionalWith the functional relationship of reservoir permeability K it is:Wherein, A, B are constant.
5. reservoir baste identification as claimed in claim 1 and physical property bearing calibration, it is characterised in that: the aobvious porosity of pressure hydrargyrum three-dimensional Porosity aobvious with casting body flake two dimensionRelation be:Wherein, C, D are constant.
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Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN108956423A (en) * | 2018-07-19 | 2018-12-07 | 中国石油大学(华东) | Determine rock two dimension porosity-three-dimensional apertures porosity quantitative relationship method |
| CN110389099A (en) * | 2018-04-23 | 2019-10-29 | 中国石油大学(北京) | The modification method and device of reservoir properties |
| CN114624163A (en) * | 2022-04-18 | 2022-06-14 | 成都理工大学 | Overburden pressure pore-permeability test-based muddiness zeolite clastic rock reservoir physical property correction method |
| CN115876668A (en) * | 2023-02-22 | 2023-03-31 | 广东石油化工学院 | Petroleum reservoir porosity measuring and calculating method based on core |
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