CN113176186A - Method for judging carbonate rock crude oil injection pressure and pore throat lower limit - Google Patents
Method for judging carbonate rock crude oil injection pressure and pore throat lower limit Download PDFInfo
- Publication number
- CN113176186A CN113176186A CN202110301441.5A CN202110301441A CN113176186A CN 113176186 A CN113176186 A CN 113176186A CN 202110301441 A CN202110301441 A CN 202110301441A CN 113176186 A CN113176186 A CN 113176186A
- Authority
- CN
- China
- Prior art keywords
- sample
- pore throat
- detected
- lower limit
- crude oil
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- 239000011148 porous material Substances 0.000 title claims abstract description 91
- 239000010779 crude oil Substances 0.000 title claims abstract description 39
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 35
- 239000011435 rock Substances 0.000 title claims abstract description 25
- 238000000034 method Methods 0.000 title claims abstract description 24
- 238000002347 injection Methods 0.000 title claims abstract description 22
- 239000007924 injection Substances 0.000 title claims abstract description 22
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 claims abstract description 39
- 229910052753 mercury Inorganic materials 0.000 claims abstract description 39
- 239000010426 asphalt Substances 0.000 claims abstract description 28
- 238000009826 distribution Methods 0.000 claims abstract description 22
- 238000003825 pressing Methods 0.000 claims abstract description 7
- 239000000523 sample Substances 0.000 claims description 76
- 238000001035 drying Methods 0.000 claims description 8
- 239000013068 control sample Substances 0.000 claims description 6
- 238000005520 cutting process Methods 0.000 claims description 5
- 238000005498 polishing Methods 0.000 claims description 4
- 238000009736 wetting Methods 0.000 claims description 3
- 238000002474 experimental method Methods 0.000 abstract description 18
- 230000007246 mechanism Effects 0.000 abstract description 5
- 238000009825 accumulation Methods 0.000 abstract description 2
- 238000005516 engineering process Methods 0.000 abstract description 2
- 238000013508 migration Methods 0.000 abstract description 2
- 230000005012 migration Effects 0.000 abstract description 2
- 239000003208 petroleum Substances 0.000 abstract description 2
- 238000011160 research Methods 0.000 abstract description 2
- 239000013589 supplement Substances 0.000 abstract description 2
- 238000012360 testing method Methods 0.000 description 8
- 230000001186 cumulative effect Effects 0.000 description 5
- 239000010459 dolomite Substances 0.000 description 5
- 229910000514 dolomite Inorganic materials 0.000 description 5
- 239000003921 oil Substances 0.000 description 4
- 238000012545 processing Methods 0.000 description 4
- 238000011161 development Methods 0.000 description 3
- 238000004458 analytical method Methods 0.000 description 2
- 230000008030 elimination Effects 0.000 description 2
- 238000003379 elimination reaction Methods 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000004575 stone Substances 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- 241000195493 Cryptophyta Species 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 125000005587 carbonate group Chemical group 0.000 description 1
- 239000010430 carbonatite Substances 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 235000009508 confectionery Nutrition 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 238000005429 filling process Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 238000010348 incorporation Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000001225 nuclear magnetic resonance method Methods 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000013074 reference sample Substances 0.000 description 1
- 238000007619 statistical method Methods 0.000 description 1
- 230000001629 suppression Effects 0.000 description 1
- 238000002411 thermogravimetry Methods 0.000 description 1
Images
Classifications
-
- 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
- G01N1/00—Sampling; Preparing specimens for investigation
- G01N1/28—Preparing specimens for investigation including physical details of (bio-)chemical methods covered elsewhere, e.g. G01N33/50, C12Q
- G01N1/34—Purifying; Cleaning
-
- 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
- G01N15/0826—Investigating permeability by forcing a fluid through a sample and measuring fluid flow rate, i.e. permeation rate or pressure change
-
- 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
-
- 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
Landscapes
- Chemical & Material Sciences (AREA)
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- Health & Medical Sciences (AREA)
- Pathology (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Dispersion Chemistry (AREA)
- Molecular Biology (AREA)
- Biomedical Technology (AREA)
- Engineering & Computer Science (AREA)
- Fluid Mechanics (AREA)
- Investigating Or Analyzing Non-Biological Materials By The Use Of Chemical Means (AREA)
Abstract
The invention relates to an experimental method in the field of petroleum geology research, in particular to a method for judging carbonate rock crude oil injection pressure and pore throat lower limit. The method for judging the injection pressure and the pore throat lower limit of the carbonate crude oil mainly comprises the following steps of: s1, preparing a sample to be detected; s2, sequentially removing asphalt from the sample to be detected and pressing mercury to obtain the pore throat diameter and pore diameter distribution information of the sample to be detected, and obtaining the pore throat lower limit value and crude oil injection pressure information of the sample to be detected according to the pore throat diameter information, wherein the asphalt removing temperature is 500 ℃ and the time is 6 hours. The method provided by the invention is based on mercury intrusion and asphalt removal experiments, provides a brand-new experimental technology for determining the filling pressure of the crude oil and the lower limit of the pore throat, supplements the contents of the filling mechanism, the accumulation theory and the like of the crude oil, provides a new thought and technical means for an oil-gas migration mechanism, and is simple, economic and rapid to operate, and more accurate in obtaining the lower limit information of the pore throat.
Description
Technical Field
The invention relates to an experimental method in the field of petroleum geology research, in particular to a method for judging the filling pressure of crude oil in a carbonate reservoir and the lower limit of an accessible pore throat by utilizing mercury intrusion and asphalt removal experiments.
Background
The carbonate reservoir has huge exploration and development values and is an important component of global oil reservoir resources. Carbonate rocks in china are widely distributed in the sichuan basin and the tarim basin. However, the space and the communication condition of the carbonate reservoirs show strong heterogeneity in space due to the influence of different sizes and structural actions in the carbonate reservoirs. However, there is no clear unified understanding of reservoir formation mechanisms, such as the carbonate reservoir crude oil filling pressure and the lower accessible pore throat. During the crude oil filling process, the filling pressure and the pore throat diameter have corresponding relation. As the inflation pressure increases, the throat diameter gradually decreases. However, there is always a lower pore throat limit that crude oil can enter, the pressure at this time is the maximum pressure during filling, and the corresponding pore throat is the lower pore throat limit.
Therefore, the filling pressure of the crude oil and the lower limit of the accessible pore throat are accurately judged, and the method is favorable for calculating the oil and gas reserves, predicting the 'engineering sweet spot' and preferably optimizing a powerful exploration and development target. The current methods for determining the lower limit of pore throat are mainly divided into two types: 1. the determination method based on dynamic production data is mainly a statistical method based on the relation between oil testing data, logging data and pore permeability distribution, and is applied to more conventional sandstone reservoirs; 2. the determination method based on the core experiment analysis result comprises a fluid saturation test, a nuclear magnetic resonance method and the like, wherein the experimental methods determine the lower limit of the pore throat according to the distribution and the empirical value of the test result, and are greatly influenced by the test condition and the sample representativeness. However, none of the above methods has been suitable for determining the carbonate rock crude oil fill pressure and lower accessible pore throat limit.
Disclosure of Invention
In view of the above, the invention provides a method for judging the filling pressure of crude oil in a carbonate reservoir and the lower limit of the accessible pore throat by using mercury intrusion and asphalt removal experiments. The method for judging the filling pressure of the crude oil and the lower limit of the accessible pore throat is provided according to the background that the development degree of the carbonate reservoir is continuously improved and the actual production requirements cannot be met by some existing experimental methods, and has the advantages of more precise lower limit of the depicted pore throat, strong repeatability and the like, and is simple, economic and rapid to operate.
The method for judging the injection pressure and the pore throat lower limit of the carbonate crude oil mainly comprises the following steps of:
s1, preparing a sample to be detected and a control sample;
s2, after asphalt removal processing is carried out on the sample to be detected, mercury pressing processing is carried out on the sample to be detected and the comparison sample respectively to obtain the pore throat diameter and the pore diameter distribution information of the sample to be detected and the comparison sample to obtain the crude oil injection pressure value, and then the pore diameter distribution value of the sample to be detected and the pore diameter distribution value of the comparison sample are subjected to difference processing to obtain the pore throat lower limit value of the sample to be detected.
Further, the specific operation of preparing the sample to be tested in S1 is as follows: and selecting a carbonate rock sample to be detected, cutting a parallel sample from the carbonate rock sample, drying and polishing to obtain the sample to be detected.
Further, the size of the sample to be detected is 1cm3。
Further, the temperature condition of drying is 60 ℃, and the time condition is 48 h.
Further, the crude oil injection pressure in S2 is obtained by the expression (1), where the expression (1) is:
in the above formula, P is filling pressure, MPa; pcCapillary force, MPa; sigma is the interfacial tension of mercury and air, 480N/m; theta is the wetting angle of mercury and rock, 140 degrees; d is the pore throat diameter, nm.
Further, the specific operation of obtaining the pore throat lower limit value of the sample to be detected in S2 is as follows: after asphalt removal treatment is carried out on a sample to be detected, mercury pressing treatment is carried out on the sample to be detected and a comparison sample respectively to obtain curves of 'pore throat diameter-pore diameter distribution (Dv/Dlogd)' of the sample to be detected and the comparison sample respectively, and difference treatment is carried out on inflection points corresponding to the pore diameter distribution of the sample to be detected and the comparison sample in the curves to obtain the pore throat lower limit value of the sample to be detected.
The technical scheme provided by the invention has the beneficial effects that: the method provided by the invention is based on mercury intrusion and asphalt removal experiments, provides a brand-new experimental technology for determining the filling pressure of the crude oil and the lower limit of the pore throat, supplements the contents of the filling mechanism, the accumulation theory and the like of the crude oil, provides a new thought and technical means for an oil-gas migration mechanism, is simple, economic and rapid to operate, is more accurate in obtaining the lower limit information of the pore throat, and has the advantages of strong repeatability and the like.
Drawings
FIG. 1 is a graph of the mercury intrusion test "pressure-cumulative mercury intrusion" for group A samples in example 1 of the present invention;
FIG. 2 is a plot of pore-throat diameter distribution (Dv/Dlogd) of mercury intrusion experiments for group A samples in example 1 of the present invention;
FIG. 3 is the "pressure-cumulative mercury intrusion" for the mercury intrusion test for group B samples in example 1 of the present invention;
FIG. 4 is a plot of pore-throat diameter distribution (Dv/Dlogd) of mercury intrusion experiments for group B samples in example 1 of the present invention;
FIG. 5 is a schematic diagram of a method for determining the carbonatite crude oil injection pressure and pore throat lower limit according to the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, embodiments of the present invention will be further described with reference to the accompanying drawings.
The principle of the method for judging the filling pressure of the crude oil in the carbonate reservoir and the lower limit of the crude oil capable of entering the pore throat by using mercury injection and asphalt removal experiments is as follows: asphalt in the carbonate rock sample is removed in a high-temperature mode, then mercury suppression experiments are combined to obtain aperture distribution of the sample which is not subjected to high-temperature removal and is subjected to high-temperature removal, the difference of vertical coordinates DV/Dlogd of two curves is compared, the pore throat diameter corresponding to the peak value with the largest difference value is the lower limit of the pore throat, and filling pressure is determined by combining a Walsh equation.
Based on the above principle, referring to fig. 5, an embodiment of the present invention provides a method for determining a lower limit of an accessible pore throat inside carbonate rock, which mainly includes the following steps:
s1, respectively preparing a sample to be detected and a control sample, wherein the specific operation steps are as follows: selecting a carbonate rock sample to be detected, cutting 2 groups of parallel samples from the carbonate rock sample by using a cutting machine, drying and polishing; selecting one group of parallel samples as an experimental group and marking as samples to be detected, and selecting the other group of parallel samples as a control group and marking as control samples;
among them, it should be noted that the two sets of parallel samples cut out by the present invention are obtained from adjacent positions of the carbonate samples in order to maximize the elimination of the influence of the heterogeneity of the carbonate. Specifically, the size of the sample to be detected and the size of the control sample are both 1cm3And 6 surfaces of the sample to be tested and the control sample are ground by a polishing machine until the surfaces are smooth and flat and have no obvious pits, so that the aim of eliminating the 'pockmark effect' of a subsequent mercury intrusion test is fulfilled. In addition, the temperature condition of the drying treatment is 60 ℃, the time condition is 48 hours, and the volatile matters in the pores of the sample are effectively removed.
S2, after asphalt removal treatment is carried out on the sample to be detected, mercury pressing treatment is respectively carried out on the sample to be detected and the comparison sample so as to respectively obtain the pore throat diameter information of the sample to be detected and the comparison sample, and the pore throat lower limit value and crude oil injection pressure information of the sample to be detected can be obtained according to the pore throat diameter information;
specifically, the sample to be tested is placed into a muffle furnace to carry out a high-temperature asphalt rejection experiment, wherein when crude oil passes through the interior of a carbonate reservoir, the crude oil can be filled in the middle of a pore network of rock particles. After crude oil cracking gas generation, oil gas molecules escape through a communicated pore network, and the rest part forms residual asphalt. The asphalt removing experiment is to remove residual asphalt in a high-temperature mode, and thermogravimetric experiment analysis of different temperature gradients shows that when the asphalt removing temperature is 500 ℃ and the time is 6 hours, asphalt in a sample can be effectively removed, and internal information of the sample can be stored to the maximum extent.
After the asphalt elimination experiment is completed, the sample to be detected and the control sample are respectively subjected to mercury pressing treatment so as to respectively obtain the pressure-fatigue of the sample to be detected and the control sampleMercury incorporation "and" pore throat diameter-pore size distribution (Dv/Dlogd) "curves. The mercury intrusion experiment is carried out by adopting an Autopore IV 9520 Micromeritics model mercury intrusion instrument, wherein the pressure condition of mercury intrusion is 0.2-60000psia, the balance time of each pressure point is 30s, and the pressure condition can realize the representation of the pore throat diameter within the range of 3 nm-800 mu m. The accumulated mercury feeding amount of the sample to be detected and the comparison sample under different pressure conditions can be obtained through a pressure-accumulated mercury feeding amount curve, and the inflection point values of the pore size distribution of the sample to be detected and the comparison sample are subjected to difference processing according to a pore throat diameter-pore size distribution (DV/Dlogd) curve to obtain the pore throat lower limit value of the sample to be detected, wherein the pore size distribution can pass through
Obtaining, ViTo be at a pressure point PiLower cumulative pore volume; vi+1To a higher pressure point Pi+1Lower cumulative pore volume; di+1For cumulative pore volume is Vi+1Pore throat diameter; diFor a cumulative pore volume of ViPore throat diameter.
The Washburn equation is often used to correlate the mercury intrusion capillary pressure with the pore throat diameter, at which point the crude oil fill pressure equals the mercury intrusion capillary pressure, the equation is calculated:
in the formula, P is filling pressure, MPa; pcCapillary force, MPa; sigma is the interfacial tension of mercury and air, 480N/m; theta is the wetting angle of mercury and rock, 140 degrees; d is the pore throat diameter, nm, so that the crude oil injection pressure information of the sample to be detected can be correspondingly obtained according to the pore throat diameter information.
< example 1>
S1, selecting five groups of carbonate rock samples to be detected with different lithofacies types, namely, residual image powder-fine crystalline dolomite (group A), gray algae clot micro-fine crystalline dolomite (group B), gray fine-mesomorphic dolomite (group C), gray laminated stone powder-fine crystalline dolomite (group D) and nucleated stone (microcrystalline) dolomite (group E), from each group, selecting the carbonate rock samples to be detected with different lithofacies types from each groupCutting 2 groups of parallel samples in the acid-salt rock sample by using a cutting machine, and drying at the drying temperature of 60 ℃ for 48 h; selecting one group of parallel samples in each group of carbonate rock samples as an experimental group and marking as samples to be detected, and selecting the other group of parallel samples as a control group and marking as control samples; the size of each group of samples is 1cm3；
S2, asphalt removal: and respectively and sequentially carrying out asphalt removal and mercury injection treatment on five groups of samples to be detected, wherein the temperature condition of asphalt removal is 500 ℃, the time is 6h, and the pressure condition of mercury injection is 0.2-60000psia, so as to respectively obtain the curves of 'pressure-accumulated mercury inflow amount' and 'pore throat diameter distribution (Dv/Dlogd)' of the five groups of samples to be detected and the five groups of reference samples. And respectively testing the Total Organic Carbon (TOC) content of the sample to be tested and the reference sample after the asphalt removal treatment, wherein the asphalt removal rates of the group A, the group B, the group C, the group D and the group E are respectively 94%, 92%, 87%, 91% and 90%, and the data show that the asphalt in the sample is effectively removed at high temperature.
The "pressure-cumulative mercury intrusion" and "pore throat diameter distribution (Dv/Dlogd)" curves for group a and group B are shown in fig. 1-4, respectively. Meanwhile, the pore throat lower limit values and the crude oil filling pressure values of five groups of samples to be measured are obtained, and the results are shown in table 1.
As shown in table 1, the lower bitumen charge pore throat limits for the 5 parallel samples of this experiment are summarized, indicating that the crude oil charge pressure and the lower accessible pore throat limits for carbonate rocks of different lithofacies types are different.
Comparing fig. 1 and fig. 3, it can be seen that the cumulative mercury intake of the group a samples is significantly increased compared to the group a control samples, and both are different from the mercury intake curve of the control samples after reaching a certain pressure.
Comparing fig. 2 and fig. 4, it can be known that the pore throat diameter distribution of the two curves is compared, the difference value of the two curves at the arrow point is the largest, and the pore throat lower limit of the sample to be measured is determined, and it can be known that the pore throat lower limit of the group a is 454nm, and the pore throat lower limit of the group B is 65 nm.
In this document, the terms front, back, upper and lower are used to define the components in the drawings and the positions of the components relative to each other, and are used for clarity and convenience of the technical solution. It is to be understood that the use of the directional terms should not be taken to limit the scope of the claims.
The features of the embodiments and embodiments described herein above may be combined with each other without conflict.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (6)
1. The method for judging the injection pressure and the pore throat lower limit of the carbonate crude oil is characterized by mainly comprising the following steps of:
s1, preparing a sample to be detected and a control sample;
s2, after asphalt removal treatment is carried out on the sample to be detected, mercury pressing treatment is carried out on the sample to be detected and the comparison sample respectively to obtain the pore throat diameter and the pore diameter distribution information of the sample to be detected and the comparison sample, and the crude oil injection pressure value and the pore throat lower limit value of the sample to be detected can be obtained according to the pore throat diameter and the pore diameter distribution information, wherein the temperature condition for asphalt removal is 500 ℃ and the time is 6 hours.
2. The method for judging the carbonate rock crude oil injection pressure and the pore throat lower limit according to claim 1, wherein the concrete operations for preparing the sample to be tested in the step S1 are as follows: and selecting a carbonate rock sample to be detected, cutting a parallel sample from the carbonate rock sample, drying and polishing to obtain the sample to be detected.
3. The method for determining carbonate rock crude oil injection pressure and pore throat lower limit according to claim 1 or 2, wherein the size of the sample to be measured is 1cm3。
4. The method for determining the injection pressure and the lower limit of pore throat of carbonate crude oil according to claim 2, wherein the drying is performed at 60 ℃ for 48 hours.
5. The method for determining carbonate crude oil injection pressure and pore throat lower limit according to claim 1, wherein the crude oil injection pressure in S2 is obtained by the formula (1), and the expression of the formula (2) is:
in the above formula, P is filling pressure, MPa; pcCapillary force, MPa; sigma is the interfacial tension of mercury and air, 480N/m; theta is the wetting angle of mercury and rock, 140 degrees; d is the pore throat diameter, nm.
6. The method for judging the carbonate rock crude oil injection pressure and the pore throat lower limit according to claim 1, wherein the specific operation of obtaining the pore throat lower limit of the sample to be tested in the step S2 is as follows: after asphalt removal treatment is carried out on a sample to be detected, mercury pressing treatment is carried out on the sample to be detected and a comparison sample respectively to obtain curves of 'pore throat diameter-pore diameter distribution (Dv/Dlogd)' of the sample to be detected and the comparison sample respectively, and difference treatment is carried out on inflection points corresponding to the pore diameter distribution of the sample to be detected and the comparison sample in the curves to obtain the pore throat lower limit value of the sample to be detected.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110301441.5A CN113176186A (en) | 2021-03-22 | 2021-03-22 | Method for judging carbonate rock crude oil injection pressure and pore throat lower limit |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110301441.5A CN113176186A (en) | 2021-03-22 | 2021-03-22 | Method for judging carbonate rock crude oil injection pressure and pore throat lower limit |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN113176186A true CN113176186A (en) | 2021-07-27 |
Family
ID=76922479
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202110301441.5A Pending CN113176186A (en) | 2021-03-22 | 2021-03-22 | Method for judging carbonate rock crude oil injection pressure and pore throat lower limit |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN113176186A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117309720A (en) * | 2023-10-07 | 2023-12-29 | 东北石油大学 | Method for representing pore throat lower limit of fluid in shale oil-gas layer by neutron scattering |
Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB8506937D0 (en) * | 1984-03-19 | 1985-04-24 | Shell Int Research | Determining pore size distribution capillary pressure |
| CN102519853A (en) * | 2011-12-05 | 2012-06-27 | 中国石油大学(华东) | Calculating method of porosity lower limit of recovery industry for effective reservoir under pore structure restraint |
| CN102706913A (en) * | 2012-06-19 | 2012-10-03 | 中国石油天然气股份有限公司 | Method and device for determining radius lower limit of reservoir formation pore throat of compact sandstone reservoir |
| CN103499594A (en) * | 2013-09-13 | 2014-01-08 | 中国石油天然气股份有限公司 | Method for measuring lower limit of feature size of crude oil movable pore throat |
| CN107228934A (en) * | 2017-06-27 | 2017-10-03 | 中国石油大学(华东) | The determination method of tight sand hydrocarbon charge pore throat radius lower limit |
| CN110726778A (en) * | 2018-07-17 | 2020-01-24 | 中国石油化工股份有限公司 | Method and system for judging lower limit of flowing croup of shale oil |
-
2021
- 2021-03-22 CN CN202110301441.5A patent/CN113176186A/en active Pending
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB8506937D0 (en) * | 1984-03-19 | 1985-04-24 | Shell Int Research | Determining pore size distribution capillary pressure |
| CN102519853A (en) * | 2011-12-05 | 2012-06-27 | 中国石油大学(华东) | Calculating method of porosity lower limit of recovery industry for effective reservoir under pore structure restraint |
| CN102706913A (en) * | 2012-06-19 | 2012-10-03 | 中国石油天然气股份有限公司 | Method and device for determining radius lower limit of reservoir formation pore throat of compact sandstone reservoir |
| CN103499594A (en) * | 2013-09-13 | 2014-01-08 | 中国石油天然气股份有限公司 | Method for measuring lower limit of feature size of crude oil movable pore throat |
| CN107228934A (en) * | 2017-06-27 | 2017-10-03 | 中国石油大学(华东) | The determination method of tight sand hydrocarbon charge pore throat radius lower limit |
| CN110726778A (en) * | 2018-07-17 | 2020-01-24 | 中国石油化工股份有限公司 | Method and system for judging lower limit of flowing croup of shale oil |
Non-Patent Citations (1)
| Title |
|---|
| 胡荣泽: "《粉末颗粒和孔隙的测量》", 28 February 1982, 冶金工业出版社 * |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117309720A (en) * | 2023-10-07 | 2023-12-29 | 东北石油大学 | Method for representing pore throat lower limit of fluid in shale oil-gas layer by neutron scattering |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Zhang et al. | A multiscale comprehensive study on pore structure of tight sandstone reservoir realized by nuclear magnetic resonance, high pressure mercury injection and constant-rate mercury injection penetration test | |
| Sun et al. | Nanoscale pore characteristics of the Lower Cambrian Niutitang Formation Shale: a case study from Well Yuke# 1 in the Southeast of Chongqing, China | |
| CN112858133B (en) | Dynamic imbibition displacement rule evaluation method for fracture of tight oil reservoir | |
| CN109991123B (en) | Geochemical evaluation method for mobility of shale oil resources | |
| CN109030311A (en) | Based on nuclear magnetic resonance T2Compose the pore structure classification and recognition methods of sensitive parameter | |
| CN110470584B (en) | Method for evaluating comprehensive effect of imbibition and water lock | |
| Huang et al. | Microscopic production characteristics of crude oil in nano-pores of shale oil reservoirs during CO2 huff and puff | |
| CN108827999B (en) | Method for evaluating movable oil proportion and movable oil resource amount of low-pore-permeability sandstone reservoir | |
| Wang et al. | Fractal characteristics of the pore structures of fine-grained, mixed sedimentary rocks from the Jimsar Sag, Junggar Basin: Implications for lacustrine tight oil accumulations | |
| CN110487693A (en) | A kind of method of determining mud shale different type porosity | |
| Ning et al. | Characteristics and controlling factors of reservoir space of mudstone and shale in Es3x in the Zhanhua Sag | |
| Wang et al. | Thermal maturity: The controlling factor of wettability, pore structure, and oil content in the lacustrine Qingshankou shale, Songliao Basin | |
| CN106777515B (en) | Method for analyzing production energy of tight gas well based on rock core experiment data | |
| CN111827996B (en) | Multi-parameter comprehensive qualitative compact sandstone reservoir classification method based on mechanical properties | |
| Jun et al. | Crude oil mobility and its controlling factors in tight sand reservoirs in northern Songliao Basin, East China | |
| CN113075102A (en) | Method for establishing mathematical model of relation between spontaneous imbibition amount of porous medium and time | |
| Ning et al. | Effect of shale reservoir characteristics on shale oil movability in the lower third member of the Shahejie Formation, Zhanhua Sag | |
| CN113533156A (en) | Identification method for microscopic pore structure characteristics and multi-type pore fluid of shale oil reservoir | |
| Wang et al. | An investigation into pore structure fractal characteristics in tight oil reservoirs: a case study of the Triassic tight sandstone with ultra-low permeability in the Ordos Basin, China | |
| CN109061099A (en) | A kind of nondestructive test evaluation method of heterogeneous tight rock degree of injury | |
| CN113176186A (en) | Method for judging carbonate rock crude oil injection pressure and pore throat lower limit | |
| CN111610126A (en) | Method and system for identifying and evaluating anti-compaction effect of dolomite reservoir pores | |
| Jiang et al. | Investigating the pore structure characteristics and reservoir capacities of lower Jurassic continental shale reservoirs in the northeastern Sichuan Basin, China | |
| CN110715879B (en) | Gas-water distribution-based method for evaluating micro-pore adsorption gas amount of highly-evolved shale reservoir | |
| Dong et al. | Factors Influencing the Pore Structure and Gas‐Bearing Characteristics of Shales: Insights from the Longmaxi Formation, Southern Sichuan Basin and Northern Yunnan‐Guizhou Depression, China |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| RJ01 | Rejection of invention patent application after publication | ||
| RJ01 | Rejection of invention patent application after publication |
Application publication date: 20210727 |