CN108169099A - A kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance - Google Patents
A kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance Download PDFInfo
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- 239000011148 porous material Substances 0.000 title claims abstract description 70
- 238000005481 NMR spectroscopy Methods 0.000 title claims abstract description 52
- 238000004364 calculation method Methods 0.000 title claims abstract description 22
- 239000011435 rock Substances 0.000 claims abstract description 40
- 239000007789 gas Substances 0.000 claims abstract description 38
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- 238000001179 sorption measurement Methods 0.000 claims abstract description 31
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 30
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 29
- 238000001228 spectrum Methods 0.000 claims abstract description 18
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 claims abstract description 15
- 229910052753 mercury Inorganic materials 0.000 claims abstract description 15
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 15
- 229910002092 carbon dioxide Inorganic materials 0.000 claims abstract description 14
- 239000001569 carbon dioxide Substances 0.000 claims abstract description 14
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 14
- 238000002474 experimental method Methods 0.000 claims abstract description 10
- 230000005311 nuclear magnetism Effects 0.000 claims abstract description 10
- 238000005259 measurement Methods 0.000 claims abstract description 8
- 238000009736 wetting Methods 0.000 claims abstract description 8
- 238000010835 comparative analysis Methods 0.000 claims abstract description 4
- 238000000034 method Methods 0.000 claims description 34
- 238000009825 accumulation Methods 0.000 claims description 10
- 230000008859 change Effects 0.000 claims description 9
- SNRUBQQJIBEYMU-UHFFFAOYSA-N dodecane Chemical compound CCCCCCCCCCCC SNRUBQQJIBEYMU-UHFFFAOYSA-N 0.000 claims description 6
- 239000012267 brine Substances 0.000 claims description 5
- 239000003079 shale oil Substances 0.000 claims description 5
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims description 5
- 239000000243 solution Substances 0.000 claims description 5
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 4
- 238000012360 testing method Methods 0.000 claims description 3
- 206010016256 fatigue Diseases 0.000 claims 1
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- 239000003921 oil Substances 0.000 description 9
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- 238000009792 diffusion process Methods 0.000 description 3
- 238000011156 evaluation Methods 0.000 description 3
- 238000012886 linear function Methods 0.000 description 3
- 230000004044 response Effects 0.000 description 3
- 230000003595 spectral effect Effects 0.000 description 3
- 238000010168 coupling process Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 230000035699 permeability Effects 0.000 description 2
- 229920006395 saturated elastomer Polymers 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- 206010049669 Dyscalculia Diseases 0.000 description 1
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 1
- GCNLQHANGFOQKY-UHFFFAOYSA-N [C+4].[O-2].[O-2].[Ti+4] Chemical compound [C+4].[O-2].[O-2].[Ti+4] GCNLQHANGFOQKY-UHFFFAOYSA-N 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- XKRFYHLGVUSROY-UHFFFAOYSA-N argon Substances [Ar] XKRFYHLGVUSROY-UHFFFAOYSA-N 0.000 description 1
- 229910052786 argon Inorganic materials 0.000 description 1
- -1 argon ion Chemical class 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 239000002734 clay mineral Substances 0.000 description 1
- 239000003245 coal Substances 0.000 description 1
- 238000000205 computational method Methods 0.000 description 1
- 230000008878 coupling Effects 0.000 description 1
- 238000005859 coupling reaction Methods 0.000 description 1
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- 239000004744 fabric Substances 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 210000000867 larynx Anatomy 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000005416 organic matter Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000005498 polishing Methods 0.000 description 1
- 238000004321 preservation Methods 0.000 description 1
- 229910052683 pyrite Inorganic materials 0.000 description 1
- NIFIFKQPDTWWGU-UHFFFAOYSA-N pyrite Chemical compound [Fe+2].[S-][S-] NIFIFKQPDTWWGU-UHFFFAOYSA-N 0.000 description 1
- 239000011028 pyrite Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
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- 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
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- G01N15/088—Investigating volume, surface area, size or distribution of pores; Porosimetry
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- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N24/00—Investigating or analyzing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects
- G01N24/08—Investigating or analyzing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
- G01N24/081—Making measurements of geologic samples, e.g. measurements of moisture, pH, porosity, permeability, tortuosity or viscosity
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Abstract
The invention discloses a kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation methods based on nuclear magnetic resonance, include the following steps：Rock core is collected；Duplicate Samples are drilled through, are carried out from oil suction, the measurement of water nuclear magnetic resonance experiment；Comparative analysis Duplicate Samples oil, water nuclear magnetic resonance T 2 spectrum difference, determine distribution of the different wetting porosity type on nuclear magnetic resonance T 2 spectrum；Shale gas reservoir full aperture distribution curve is obtained according to high-pressure mercury, nitrogen adsorption, carbon dioxide adsorption；Further, aperture and corresponding T2 times crossplot are obtained；According to different aperture type aperture and the crossplot of corresponding T2 values, point porosity type establishes the quantitative calculation in aperture.The advantage of the invention is that：The technology can quantify and calculate shale gas reservoir pore space full aperture distribution curve；Meanwhile nuclear-magnetism measurement is quick, simple, lossless, it is stronger compared to high-pressure mercury, nitrogen adsorption, carbon dioxide adsorption practicability；Compared to conventional method, result of calculation is more accurate.
Description
Technical field
The present invention relates to shale gas RESERVOIR PORE STRUCTURE assessment technique field, more particularly to a kind of page based on nuclear magnetic resonance
Rock gas reservoir pore structure quantitative calculation method.
Background technology
Shale gas refers mainly to the natural gas in shale matrix pores or crack with ADSORPTION STATE or free state preservation.Shale gas
It is the unconventional petroleum resources that another is important after compact sandstone gas and coal bed gas.At present, shale gas reservoir pore space is evaluated
The experimental method of structure mainly includes：Scanning electron microscope, high-pressure mercury, nitrogen adsorption, carbon dioxide adsorption, nuclear magnetic resonance etc. are real
It tests；
(1) scanning electron microscope, pressure mercury, nitrogen adsorption, carbon dioxide adsorption
Scanning electron microscope combination argon ion polishing technology can carry out qualitative observation, but be difficult to quantitatively characterizing shale to pore structure
The pore structure characteristic of gas reservoir.High-pressure mercury, nitrogen adsorption, carbon dioxide adsorption experiment can obtain quantitative response reservoir pore space
The pore size distribution curve of structure.However, because of the difference of its experimental principle, experiment condition, mercury injection method mainly characterizes>The hole of 50nm
Diameter, nitrogen adsorption methods mainly characterize the aperture of 2~50nm, and carbon dioxide adsorption method mainly characterizes<The aperture of 2nm；Therefore, not
It can obtain the pore size distribution curve of objective characterisation reservoir micropore structure.
(2) nuclear magnetic resonance evaluation pore structure
Nuclear magnetic resonance logging data evaluation RESERVOIR PORE STRUCTURE has its unique advantage；Nuclear magnetic resonance evaluates conventional sandstone or carbonic acid
The Method And Principle of rock salt RESERVOIR PORE STRUCTURE is as follows：
By NMR relaxation mechanism it is found that the lateral relaxation time T2 observed can be expressed as
In formula：Volume (freedom) relaxation times of the T2B for fluid, ms；D is diffusion coefficient, μm2/ms；G is magnetic field gradient,
gauss/cm；TE is echo sounding, ms；R is pore radius, um；ρ is the lateral surfaces relaxation strength of rock, μm/s, by hole
The influence of surface wettability, i.e., it is related with porosity type.Fs is the pore shape factor, for spherical hole, Fs=3；And
For column pipeline, Fs=2.
For diffusion relaxation item (Section 3 on the right of equation), when using smaller echo sounding (TE=0.06ms) and uniformly
During magnetic field observation, then either saturated water or saturated oils condition, diffusion relaxation item can be ignored.Above formula becomes：
Normal conditions, fluid volume relaxation T2B are more much bigger (T2B than the T2 relaxation times>>T2).Therefore, equal sign in formula 1
The right first item Volume Relaxation part can ignore to get to：
R=ρ Fs×T2 (4)
R=C × T2 (5)
In formula：C=ρ Fs.The key of nuclear-magnetism evaluation reservoir pores r is the accurately relationship of determining C or determining formula (5)
Formula；
At present, mainly include three classes using the method for nuclear magnetic resonance characterization reservoir micropore structure：Linear function scale
Method, J functions and SDR models couplings method, classification subsection power function method.He Yudan et al. is it was verified that linear function scale method structure
The capillary pressure curve built and experiment capillary pressure curve are larger in aperture larynx fractional error, and effect is undesirable；Classification segmentation power
Function method overcomes linear function scale method aperture throat point effect is undesirable the shortcomings that；But this method needs known store up
The porosity of layer, permeability could build capillary pressure curve after classifying to reservoir；Since shale gas reservoir properties are poor,
The dyscalculia of porosity and permeability, similar to classification subsection power function method, J functions and SDR models coupling methods fail to solve
The determining problem of J function category standards so that the utilization of the method is also restrained.However the above method is for sandstone or carbon
The conventional reservoirs such as hydrochlorate, it is less to the research of shale gas reservoir micropore structure nuclear-magnetism characterization.
For the evaluation of shale gas RESERVOIR PORE STRUCTURE, Li Jun et al. in periodical《Logging technique》On delivered an article
《Shale gas rock core nuclear magnetic resonance T2 and aperture size quantitative relationship》, it is believed that C values are 47 μm/s.But for shale gas reservoir
Complex Rock component, porosity type, the value not should be definite value, i.e., do not consider that surface is relaxed in shale different wetting hole component type
The difference of Henan rate.
Invention content
The present invention in view of the drawbacks of the prior art, provides a kind of shale gas RESERVOIR PORE STRUCTURE based on nuclear magnetic resonance and determines
Computational methods are measured, can effectively solve the problem that the above-mentioned problems of the prior art.
In order to realize more than goal of the invention, the technical solution that the present invention takes is as follows：
A kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance, includes the following steps：
Step 1, rock core is collected；
Step 2, Duplicate Samples are drilled through, are carried out from oil suction, the measurement of water nuclear magnetic resonance experiment；
Drill through cylindric shale oil and gas reservoir rock core；The rock core is cut from centre, it is smooth to be prepared as end face, similar length
One group of Duplicate Samples, two pieces of core numbers are respectively a, b；Rock core a self-primings brine, another piece of rock core b are selected from oil suction；According to rock
Sample nuclear magnetic resonance parameter tests specifications of surveys, carries out Nuclear Magnetic Resonance Measurement to two blocks of rock cores, obtains the nuclear magnetic resonance of two blocks of rock cores
T2 is composed；
Step 3, comparative analysis Duplicate Samples oil, water nuclear-magnetism T2 resonance spectrum differences, determine different wetting porosity type in core
Distribution in magnetic resonance T2 spectrums；
Step 4, shale gas reservoir full aperture distribution curve is obtained according to high-pressure mercury, nitrogen adsorption, carbon dioxide adsorption；
Step 5, aperture and corresponding nuclear magnetic resonance T2 time crossplots are obtained；
It is descending by aperture by shale full aperture distribution curve, the corresponding saturation degree in each aperture is added up, is obtained
To accumulative saturation degree and the change curve in aperture；It is descending by T2 values to full water nuclear magnetic resonance T 2 spectrum, every T2 values are corresponded to
Saturation degree added up, obtain accumulation saturation degree and T2 change curve.
It is bent in the change curve in accumulative saturation degree and aperture and the variation of accumulation saturation degree and T2 using equisaturation principle
The T2 values corresponding to the aperture under same accumulation saturation degree are found in line；According to the corresponding T2 values in aperture, cross plot is done；Base
In step 3, the porosity type carried out to different T2 values divides, further by porosity type difference, by the friendship in cross plot
It can put and be divided into three parts；Different aperture type (organic hole, inorganic hole, microcrack) is presented different between T2 times and aperture
Variation tendency, the difference of variation tendency may be due to the shape of hole corresponding to different aperture type and pore surface relaxation
Caused by the difference of Henan rate.
Step 6, according in step 5, the crossplot of different aperture type aperture and corresponding T2 times, a point porosity type are built
The quantitative calculation in vertical aperture；
To different aperture type aperture and T2 values, using exponential function form, aperture and the relational expression of T2 are fitted, has been shown in Table
1。
Table 1
Based on nuclear magnetic resonance T 2 spectrum, according to the formula in table 1, by porosity type difference, different T2 values ranges is used
Different calculation formula, is calculated aperture in table 1.
Preferably, cylindric shale oil and gas reservoir core diameter is 2.54cm or 3.81cm in step 2, length is more than
6cm。
Preferably, rock core a self-primings brine is the Nacl solution of 40000ppm in step 2.
Preferably, in step 2 rock core b from oil suction be dodecane.
Preferably, rock core self-priming time is 48 hours in step 2.
Further, step 4 is as follows：1) shale is analyzed using high-pressure mercury method, with reference to
Washburn equations obtain the pore volume in each aperture in the first pore diameter range；2) using nitrogen adsorption methods to the first powdery shale
It is analyzed, the pore volume in each aperture in the second pore diameter range is obtained with reference to BJH models；3) using carbon dioxide adsorption method pair
Second powdery shale is analyzed, and the pore volume in each aperture in third pore diameter range is obtained with reference to DFT models；4) such as the first hole
Model is overlapped between diameter range, the second pore diameter range and third pore diameter range, each hole in overlapping range is obtained using weighted mean method
The pore volume of diameter.Obtain shale full aperture distribution curve.
Compared with prior art the advantage of the invention is that：
(1) conventional means of the characterization such as high-pressure mercury, nitrogen adsorption, carbon dioxide adsorption shale gas pore-size distribution and side
There is limitation in method, i.e., mercury injection method mainly characterizes in the range of aperture characterization>The aperture of 50nm, the main table of nitrogen adsorption methods
The aperture of 2~50nm is levied, carbon dioxide adsorption method mainly characterizes<The aperture of 2nm；The technology can quantify and calculate shale gas reservoir
Hole full aperture distribution curve；Meanwhile nuclear-magnetism measurement is quick, simple, lossless, compared to high-pressure mercury, nitrogen adsorption, titanium dioxide
Carbon adsorption practicability is stronger.
(2) technology considers the shadow that different aperture type and its wetting sex differernce in shale characterize nuclear-magnetism pore-size distribution
It rings, compared to conventional method, result of calculation is more accurate.
Description of the drawings
Fig. 1 is the nuclear magnetic resonance T 2 spectrum figure of two blocks of rock cores of the embodiment of the present invention；
Fig. 2 is shale full aperture distribution map of the embodiment of the present invention；
Fig. 3 is the reversed accumulation curve in aperture of shale samples of embodiment of the present invention H10；
Fig. 4 is the T2 distribution reversal accumulation curves of shale samples of embodiment of the present invention H10；
Fig. 5 is shale samples of embodiment of the present invention different pore size and corresponding T2 times cross plot；
Fig. 6 is predicted for LM1 of embodiment of the present invention nuclear magnetic resonance with surveying pore-size distribution comparison diagram；
Fig. 7 is predicted for LM2 of embodiment of the present invention nuclear magnetic resonance with surveying pore-size distribution comparison diagram；
Fig. 8 is predicted for LM3 of embodiment of the present invention nuclear magnetic resonance with surveying pore-size distribution comparison diagram；
Fig. 9 is predicted for LM4 of embodiment of the present invention nuclear magnetic resonance with surveying pore-size distribution comparison diagram；
Figure 10 is predicted for H10 of embodiment of the present invention nuclear magnetic resonance with surveying pore-size distribution comparison diagram.
Specific embodiment
To make the objectives, technical solutions, and advantages of the present invention more comprehensible, develop simultaneously embodiment referring to the drawings, right
The present invention is described in further details.
A kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance, includes the following steps：
Step 1, rock core is collected；
Step 2, Duplicate Samples are drilled through, are carried out from oil suction, the measurement of water nuclear magnetic resonance experiment；
Drill through a diameter of 2.54cm (or 3.81cm), length is more than the cylindric shale oil and gas reservoir rock cores of 6cm；By the rock core
It is cut from centre, is prepared as that end face is smooth, one group of Duplicate Samples of similar length (two pieces of core numbers are respectively a, b)；Select rock
Heart a self-primings brine (the Nacl solution of 40000ppm), another piece of rock core b are from oil suction (dodecane)；Rock core self-priming time is small for 48
When.According to rock sample nuclear magnetic resonance parameter experiment specifications of surveys (SY/T 6490-2007), nuclear magnetic resonance survey is carried out to two blocks of rock cores
Amount, obtains the nuclear magnetic resonance T 2 spectrum of two blocks of rock cores, as shown in Figure 1.
Step 3, comparative analysis Duplicate Samples oil, water nuclear magnetic resonance T 2 spectrum difference, determine different wetting porosity type in core
Distribution in magnetic resonance T2 spectrums；
Duplicate Samples rock core is compared from oil suction, the difference of Absorb Water nuclear magnetic resonance T 2 spectrum, thinks that rock core nuclear-magnetism T2 spectrums exist accordingly
Spectral peak (P1) between 0.01~0.3ms is mainly related with the response of proton in organic matter, that is, corresponds to organic hole (glossy wet)；
Spectral peak (P2) between 0.3~10ms is mainly by (clay mineral intergranular pore and intracrystalline pore, pyrite intracrystalline pore) hydrogen in inorganic hole
The response of core causes, that is, corresponds to inorganic hole (water wetting)；>The spectral peak (P3) of 10ms corresponds to microcrack (mixing wetting).
Step 4, shale gas reservoir full aperture distribution curve is obtained according to high-pressure mercury, nitrogen adsorption, carbon dioxide adsorption；
It is as follows：1) shale is analyzed using high-pressure mercury method, first is obtained with reference to washburn equations
The pore volume in each aperture in pore diameter range；2) the first powdery shale is analyzed using nitrogen adsorption methods, with reference to BJH models
Obtain the pore volume in each aperture in the second pore diameter range；3) the second powdery shale is divided using carbon dioxide adsorption method
Analysis, the pore volume in each aperture in third pore diameter range is obtained with reference to DFT models；4) such as the first pore diameter range, the second aperture model
It encloses and is overlapped model between third pore diameter range, the pore volume in each aperture in overlapping range is obtained using weighted mean method.Foundation
Step and method shown in the patent obtain shale full aperture distribution curve, as shown in Figure 2.
Step 5, aperture and corresponding nuclear magnetic resonance T2 time crossplots are obtained
For petrophysics angle, what Fig. 2 pore size distribution curves reflected is the hole under a certain pore size control
The distribution of volume.What nuclear magnetic resonance T2 distributions equally reflected is the porosity component under a certain aperture.Pore size distribution curve and T2
The meaning that distribution curve is characterized is the same, but since the cloth points of pore size distribution curve and T2 distribution curves have differences, because
This is difficult to directly compare by form, and corresponding T2 values are obtained from pore size distribution curve.
For this purpose, by shale full aperture distribution curve in Fig. 2, to each aperture corresponding saturation degree descending by aperture
Added up, obtain the change curve in accumulative saturation degree and aperture, such as Fig. 3；To in Fig. 1 full water nuclear-magnetism T2 compose, by T2 values by
It arrives greatly small, the corresponding saturation degree of every T2 values is added up, obtain accumulation saturation degree and the change curve of T2, such as Fig. 4.
Using " equisaturation " principle, the T2 corresponding to the aperture under same accumulation saturation degree is found in Fig. 3 and Fig. 4
Value.According to the corresponding T2 values in aperture, do cross plot and obtain Fig. 5 based on the hole in step 3, carried out to different T2 values
Plotted point in cross plot 5 further by porosity type difference, is divided into three parts by Type division.Different aperture class in Fig. 5
Different variation tendencies are presented in type (organic hole, inorganic hole, microcrack) between T2 times and aperture, the difference of variation tendency may
It is caused by the shape of hole corresponding to different aperture type and the difference of pore surface relaxation rate.
Step 6, according in step 5, the crossplot of different aperture type aperture and corresponding T2 values, a point porosity type is established
The quantitative calculation in aperture
To different aperture type aperture in Fig. 5 and T2 values, using exponential function form, it is fitted aperture and the relationship of T2
Formula is shown in Table 1.
1 shale gas reservoir pores transformation model of table
Based on nuclear magnetic resonance T 2 spectrum, according to the formula in table 1, i.e., by porosity type difference, different T2 value ranges are adopted
With different calculation formula, aperture can be calculated.Fig. 6~Figure 10 shows that the pore-size distribution of nuclear-magnetism prediction and experiment measure aperture
The identical property of distribution is preferable；The shale gas RESERVOIR PORE STRUCTURE quantitative calculation method that this patent proposes is reliable.
Those of ordinary skill in the art will understand that the embodiments described herein, which is to help reader, understands this hair
Bright implementation, it should be understood that protection scope of the present invention is not limited to such specific embodiments and embodiments.Ability
The those of ordinary skill in domain can be made according to these technical inspirations disclosed by the invention it is various do not depart from essence of the invention its
Its various specific deformation and combination, these deformations and combination are still within the scope of the present invention.
Claims (6)
1. a kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance, it is characterised in that including following step
Suddenly：
Step 1, rock core is collected；
Step 2, Duplicate Samples are drilled through, are carried out from oil suction, the measurement of water nuclear magnetic resonance experiment；
Drill through cylindric shale oil and gas reservoir rock core；The rock core from centre is cut, is prepared as that end face is smooth, the one of similar length
Group Duplicate Samples, two pieces of core numbers are respectively a, b；Rock core a self-primings brine, another piece of rock core b are selected from oil suction；According to rock sample core
Magnetic resonance parameters test specifications of surveys, carry out Nuclear Magnetic Resonance Measurement to two blocks of rock cores, obtain the nuclear magnetic resonance T 2 spectrum of two blocks of rock cores；
Step 3, comparative analysis Duplicate Samples oil, water nuclear magnetic resonance T 2 spectrum difference, determine that different wetting porosity type is total in nuclear-magnetism
The distribution shaken in T2 spectrums；
Step 4, shale gas reservoir full aperture distribution curve is obtained according to high-pressure mercury, nitrogen adsorption, carbon dioxide adsorption；
Step 5, aperture and corresponding nuclear magnetic resonance T2 time crossplots are obtained；
It is descending by aperture by shale full aperture distribution curve, the corresponding saturation degree in each aperture is added up, is tired out
Count the change curve in saturation degree and aperture；It is descending by T2 values to full water nuclear magnetic resonance T 2 spectrum, it is corresponding to every T2 values full
Added up with degree, obtain accumulation saturation degree and the change curve of T2；
Using equisaturation principle, in accumulative saturation degree and the change curve in aperture and the change curve of accumulation saturation degree and T2
Find the T2 values corresponding to the aperture under same accumulation saturation degree；According to the corresponding T2 values in aperture, cross plot is done；Based on step
In rapid 3, the porosity type carried out to different T2 values divides, further by porosity type difference, by the plotted point in cross plot
It is divided into three parts；Organic hole, inorganic hole and microcrack are included for porosity type, presented between T2 times and aperture different
Variation tendency, the difference of variation tendency may be due to the shape of hole corresponding to different aperture type and pore surface relaxation
Caused by the difference of rate；
Step 6, according in step 5, the crossplot of different aperture type aperture and corresponding T2 times, a point porosity type establish hole
The quantitative calculation of diameter；
To different aperture type aperture and T2 values, using exponential function form, aperture and the relational expression of T2 are fitted, has been shown in Table 1；
Table 1
Based on nuclear magnetic resonance T 2 spectrum, according to the formula in table 1, by porosity type difference, to different T2 values ranges using in table 1
Different calculation formula, is calculated aperture.
2. a kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance according to claim 1,
It is characterized in that：Cylindric shale oil and gas reservoir core diameter is 2.54cm or 3.81cm in step 2, length is more than 6cm.
3. a kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance according to claim 1,
It is characterized in that：Rock core a self-primings brine is the Nacl solution of 40000ppm in step 2.
4. a kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance according to claim 1,
It is characterized in that：In step 2 rock core b from oil suction be dodecane.
5. a kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance according to claim 1,
It is characterized in that：Rock core self-priming time is 48 hours in step 2.
6. a kind of shale gas RESERVOIR PORE STRUCTURE quantitative calculation method based on nuclear magnetic resonance according to claim 1,
It is characterized in that：Step 4 is as follows：1) shale is analyzed using high-pressure mercury method, with reference to washburn equations
Obtain the pore volume in each aperture in the first pore diameter range；2) the first powdery shale is analyzed using nitrogen adsorption methods, tied
It closes BJH models and obtains the pore volume in each aperture in the second pore diameter range；3) using carbon dioxide adsorption method to the second powdery page
Rock is analyzed, and the pore volume in each aperture in third pore diameter range is obtained with reference to DFT models；4) such as the first pore diameter range, the
Model is overlapped between two pore diameter ranges and third pore diameter range, the pore-body in each aperture in overlapping range is obtained using weighted mean method
Product.Obtain shale full aperture distribution curve.
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