CN109060639A - A kind of measuring method of long cores permeability saturation curve - Google Patents
A kind of measuring method of long cores permeability saturation curve Download PDFInfo
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- CN109060639A CN109060639A CN201811166808.1A CN201811166808A CN109060639A CN 109060639 A CN109060639 A CN 109060639A CN 201811166808 A CN201811166808 A CN 201811166808A CN 109060639 A CN109060639 A CN 109060639A
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- 238000000034 method Methods 0.000 title claims abstract description 41
- 230000035699 permeability Effects 0.000 title claims abstract description 37
- 239000011435 rock Substances 0.000 claims abstract description 76
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 70
- 239000007788 liquid Substances 0.000 claims abstract description 29
- 239000012530 fluid Substances 0.000 claims abstract description 28
- 238000004519 manufacturing process Methods 0.000 claims abstract description 28
- 238000002347 injection Methods 0.000 claims abstract description 21
- 239000007924 injection Substances 0.000 claims abstract description 21
- 150000003839 salts Chemical class 0.000 claims abstract description 17
- 239000011148 porous material Substances 0.000 claims abstract description 15
- 238000006073 displacement reaction Methods 0.000 claims abstract description 9
- 229920006395 saturated elastomer Polymers 0.000 claims abstract description 9
- 238000009533 lab test Methods 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 27
- 238000012360 testing method Methods 0.000 description 7
- 238000002474 experimental method Methods 0.000 description 5
- 238000005303 weighing Methods 0.000 description 4
- 238000010586 diagram Methods 0.000 description 3
- 239000012153 distilled water Substances 0.000 description 3
- 238000010606 normalization Methods 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 230000001186 cumulative effect Effects 0.000 description 2
- 239000007789 gas Substances 0.000 description 2
- 238000001764 infiltration Methods 0.000 description 2
- 230000008595 infiltration Effects 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 238000002360 preparation method Methods 0.000 description 2
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- 239000006004 Quartz sand Substances 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- XLYOFNOQVPJJNP-ZSJDYOACSA-N heavy water Substances [2H]O[2H] XLYOFNOQVPJJNP-ZSJDYOACSA-N 0.000 description 1
- 230000008676 import Effects 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 238000005325 percolation Methods 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 230000006641 stabilisation Effects 0.000 description 1
- 238000011105 stabilization Methods 0.000 description 1
Classifications
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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
- 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
- G01N15/0893—Investigating volume, surface area, size or distribution of pores; Porosimetry by measuring weight or volume of sorbed fluid, e.g. B.E.T. method
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N5/00—Analysing materials by weighing, e.g. weighing small particles separated from a gas or liquid
- G01N5/02—Analysing materials by weighing, e.g. weighing small particles separated from a gas or liquid by absorbing or adsorbing components of a material and determining change of weight of the adsorbent, e.g. determining moisture content
- G01N5/025—Analysing materials by weighing, e.g. weighing small particles separated from a gas or liquid by absorbing or adsorbing components of a material and determining change of weight of the adsorbent, e.g. determining moisture content for determining moisture content
-
- 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
- G01N2015/0866—Sorption
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- Chemical & Material Sciences (AREA)
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- General Health & Medical Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
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- Pathology (AREA)
- Dispersion Chemistry (AREA)
- Fluid Mechanics (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
Abstract
The invention discloses a kind of measuring methods of long cores permeability saturation curve.Described method includes following steps: measuring the pore volume of rock core；Displacement is carried out to rock core using salt water, interval collects production fluid and surveys conductivity, when conductivity value is no longer changed, stops injection；The relation curve between the conductivity value and salt water injection pore volume of production fluid is drawn, and then judges the homogenieity of rock core；Rock core is placed vertically, inject oil from the top of rock core and is saturated, liquid to no aquatic products is connect from the bottom of rock core and goes out, measures output liquid measure, calculates irreducible water saturation；From the bottom of rock core, injection water carries out water drive oil, and liquid is connect at the top of rock core, aqueous oil content and injection pressure, calculation of water gas relative permeability in different time periods is recorded, obtains the permeability saturation curve of rock core.For small rock core, the method for the present invention is more accurate to the metering of experimental data, and precision is higher, while carrying out oil reservoir simulating lab test using the biggish long cores of scale and being more in line with reality.
Description
Technical field
The present invention relates to a kind of measuring methods of long cores permeability saturation curve, belong to Oil and Natural Gas Engineering neck
Domain.
Background technique
Permeability saturation curve is one of most important data of oil reservoir basic research work, in the predictable oil of different development phases
Well production, water-oil factor, oil well produce water rule, oil displacement efficiency and recovery ratio etc..Its order of accuarcy will directly affect people to oil
The understanding and various calculating of water driving characteristics are hidden, therefore correctly seek the representational oil-water relative permeability curve of oil reservoir to be
Highly important work.At present for the measurement of permeability saturation curve, mostly based on standard SY/T5345-2007 " two in rock
Phase fluid relative permeability measuring method ", use it is mostly be natural coring small rock core, such as application No. is 201611094637.7
Patent disclose a kind of tight sand steady state method Gas And Water Relative Permeability curve determination method, use is small rock core；And
In order to overcome end effect, document " phase percolation curve of different location calculates in long core flooding " is spelled using the small rock core of muti-piece
Long cores are connected into, but core permeability are calculated too complicated.Simultaneously because small core test permeability saturation curve is to output
The measuring requirement of liquid is higher, is easy to produce error, and cannot simulate thick oil pay condition using small rock core.
Summary of the invention
The object of the present invention is to provide a kind of method for measuring large scale long cores permeability saturation curve, the present invention is used
Cold store enclosure places rock core vertically, and verifies rock core homogenieity using conductivity, measures oil-water relative permeability curve, can
To obtain accurate permeability saturation curve under higher production fluid reading accuracy.
The measuring method of long cores permeability saturation curve provided by the present invention, includes the following steps:
(1) dry weight for measuring rock core measures the weight in wet base of the rock core to saturated water after the rock core vacuumizing, and then obtains
To the pore volume of the rock core；
The length of the rock core is 20~30cm；
(2) constant speed displacement is carried out to the rock core using salt water, interval collects production fluid and measures conductivity value, when described
When the conductivity value of production fluid is no longer changed, stop injecting the salt water；Draw conductivity value and the institute of the production fluid
The relation curve between the injection pore volume of salt water is stated, and then judges the homogenieity of the rock core；
(3) rock core is placed vertically, inject oil from the top of the rock core and be saturated, connect from the bottom of the rock core
Liquid to no aquatic products goes out, and measures output liquid measure, calculates irreducible water saturation；
(4) from the bottom of the rock core, injection water carries out water drive oil, and liquid is connect at the top of the rock core, records different time
The aqueous oil content and injection pressure, calculation of water gas relative permeability of section, and then obtain the permeability saturation curve of rock core.
In above-mentioned measuring method, in step (1), the dry weight and weight in wet base of the rock core are measured using electronic balance；To institute
It states until rock core carries out being evacuated to critical pressure standard value -0.092MPa, the core quality M after weighing saturated water1ˊ is determined
Its pore volume V=(M1ˊ-M1)/ρWater, M1The quality of the rock core before expression saturated water.
In above-mentioned measuring method, step (2) can carry out as steps described below: with distilled water needed for electronic balance weighing and
Inorganic salts prepare the salinity that salt water is setting, measure its conductivity value with conductivity meter, preparation is filled in intermediate receptacle
Salt water has been sequentially connected ISCO pump, intermediate receptacle and rock core with pipeline, is pumped salt water with ISCO with the speed of v mL/min from rock
The injection of heart arrival end carries out displacement, and fixation connects liquid time interval, and production fluid is sub-packed in multiple test tubes according to liquid sequence is connect,
And production fluid conductivity is measured, until conductivity value reaches stable, such as at interval of t s, successively exported in rock core using small test tube
End carries out connecing liquid, until the conductivity value of production fluid reaches stable, injection rate is no less than 1 times of pore volume (1PV), uses DDS-
The conductivity value of production fluid, records the corresponding note of each conductivity value in 11A digital display conductivity meter METHOD FOR CONTINUOUS DETERMINATION same time interval
The relation curve of conductivity value and injection pore volume, testing rock core homogenieity are drawn out in the angle of incidence.
In above-mentioned measuring method, in step (3), the irreducible water saturation is calculated according to the following formula:
Swi=(v ˊ × T-Vwater)/Voil；
In formula, VwaterIndicate the water of output, VoilIndicate the oil mass of output, unit is mL；
V ˊ indicates it is the oily flow velocity of injection, unit mL/min；
T indicates injection length, unit min.
In above-mentioned measuring method, step (4) can carry out as steps described below: the horizontal valve at core import and export end is closed
It closes, it is vertical to place, the horizontal valve of entrance end is opened, saturated oils is carried out from rock core bottom end with the flow velocity of v ˊ mL/min, in rock core
Top connects liquid, at water breakthrough initial stage, interval encryption connect liquid (refer to and connect liquid initial stage, it is very short to connect liquid interval time, behind gradually increase and connect liquid
Interval time), successively according at interval of t1min、t2min、t3min、t4min…(t1<t2<t3<t4< ...) liquid is connect to no oil production
Out, the pressure difference in displacement process is recorded, the moisture content and oil content in production fluid are calculated, and the opposite infiltration of the water phase for calculating each moment
Saturating rate Krw and oil relative permeability Kro and rock sample exit-end water saturation Sw.
Further, according to experimental procedure, production fluid data and acquisition pressure are handled using J.B.N method, finally
Obtain permeability saturation curve.
The formula that the J.B.N method of use is related to is as follows:
Wherein,
fo(Sw)-oil content, decimally indicates；
- zero dimension cumulative recovery, with the fraction representation of pore volume；
- zero dimension accumulates Discharge rate, with the fraction representation of pore volume；
I-is with respect to injectability, also known as fluid ability ratio；
Qo- initial time rock sample exit end face oil-producing flow, (cm3/s)；
Q (t)-t moment rock sample exit end face production fluid flow amount, Q (t)=Q when constant speed method is testedo, (cm3/s)；
ΔPo- pressure difference is initially driven, (MPa)；
The numerical value of Δ P (t)-t moment displacement pressure difference, Δ P (t)=Δ P when constant-voltage method is testedo, (MPa)；
Swi- irreducible water saturation, decimally indicates；
Swe- rock sample exit end face water saturation, decimally indicates.
The advantages of measuring method of the present invention: the invention proposes a kind of measuring method of long cores permeability saturation curve,
More accurate to the metering of experimental data for small rock core, precision is higher, at the same using the biggish long cores of scale into
Row oil reservoir simulating lab test is more in line with reality.
Detailed description of the invention
Fig. 1 is long cores scale diagrams.
Fig. 2 is rock core homogenieity test chart.
Fig. 3 is production fluid datagram.
Fig. 4 is the method for the present invention experiment gained permeability saturation curve figure.
Fig. 5 is that normalization calculates permeability saturation curve and experiment gained permeability saturation curve comparison diagram.
Specific embodiment
Experimental method used in following embodiments is conventional method unless otherwise specified.
The materials, reagents and the like used in the following examples is commercially available unless otherwise specified.
Using the quartz sand making artificial rock core of the single mesh number of 60~80 mesh, measure rock core having a size of 4.5cm × 4.5cm ×
The long cores of 29.66cm, as shown in Figure 1, carrying out vacuumizing saturation distilled water, until critical pressure standard value-after weighing dry weight
Until 0.092MPa, after being sufficiently saturated distilled water, weighing, calculating pore volume is 129.11mL.Match salt manufacturing using 10L distilled water
Water, composition are as shown in the table.
Table 1 prepares salt water composition
| Ingredient | Content (mg/L) |
| CaCl2:2H2O | 700 |
| NaCl | 5000 |
Preparation salt water salinity is 5700mg/L, and measuring its conductivity value with DDS-11A digital display conductivity meter is 9000 μ s/
Rock core is horizontally arranged by cm, has been sequentially connected ISCO pump, intermediate receptacle and rock core with pipeline, has been pumped with ISCO with the speed of 4mL/min
Degree injects salt water in rock core, carries out displacement, with the interval time of 1min, successively terminates liquid in the outlet of rock core with test tube, surveys
Determine the conductivity value of production fluid in test tube, until conductivity value is no longer changed, stop injection, injection rate is pore-body at this time
Long-pending 3 times.With the conductivity of production fluid in DDS-11A digital display conductivity meter every section of time interval of sequentially determining, production fluid is drawn
The relation curve of conductivity value and injection pore volume, as shown in Figure 2.
According to application No. is a kind of 2016109617561 application for a patent for invention (denominations of invention are as follows: evaluation rock core is heterogeneous
The method of degree) provide method, judge that rock core belongs to homogeneous rock core from conductivity variations figure.Rock core is placed vertically, from rock
Saturated oils is carried out to pressure stabilization with the flow velocity of 0.2mL/min at the top of the heart and is not discharged, water yield and steady pressure are recorded, is calculated
Irreducible water saturation.Then from rock core bottom, water drive oil is carried out with the flow velocity of 0.2mL/min, every 20min acquires a production fluid
Data, until interval encryption connects liquid when just having started water breakthrough, it is primary to connect liquid at interval of 5min, after connecing 20, connects liquid at interval of 10min
Once, after connecing 10, it is primary that liquid is connect at interval of 20min, and after connecing 10, it is primary to connect liquid at interval of 40min, after connecing 10, every
It is primary that liquid is connect every 1h, until moisture content reaches 98% in production fluid, is recorded production fluid data and injection pressure, is calculated opposite infiltration
Rate curve, as shown in Figure 4.
Gained production fluid data are as shown in Figure 3.
The water phase relative permeability Krw and oil relative permeability Kro and rock sample at each moment are calculated using J.B.N method
Exit-end water saturation Sw.
Wherein,
fo(Sw)-oil content, decimally indicates；
- zero dimension cumulative recovery, with the fraction representation of pore volume；
- zero dimension accumulates Discharge rate, with the fraction representation of pore volume；
I-is with respect to injectability, also known as fluid ability ratio；
Qo- initial time rock sample exit end face oil-producing flow, (cm3/s)；
Q (t)-t moment rock sample exit end face production fluid flow amount, Q (t)=Q when constant speed method is testedo, (cm3/s)；
ΔPo- pressure difference is initially driven, (MPa)；
The numerical value of Δ P (t)-t moment displacement pressure difference, Δ P (t)=Δ P when constant-voltage method is testedo, (MPa)；
Swi- irreducible water saturation, decimally indicates；
Swe- rock sample exit end face water saturation, decimally indicates.
In order to verify the accuracy of curve, on the basis of above-mentioned embodiment, repeatability has been carried out using same method
Experiment.Meanwhile using method for normalizing, permeability saturation curve is handled, acquired results are as shown in Figure 5.
Kro=a (1-SwD)m
Wherein,
SWD- normalization water saturation；
Swi- irreducible water saturation；
Swo- residual oil saturation；
M, n-parameter related with rock core.
It can be seen that relative permeability obtained by normalization permeability saturation curve and the method for the present invention from comparison diagram 4 and Fig. 5
The trend of curve is almost the same, and the permeability saturation curve for illustrating that measuring method of the present invention obtains is accurate, established long cores phase
It is feasible to permeability curve measuring method.
The above is only a preferred embodiment of the present invention, it is noted that the invention is not limited to aforesaid way,
Without departing from the principles of the invention, moreover it is possible to be further improved, these improvement also should be regarded as protection scope of the present invention.
Claims (4)
1. a kind of measuring method of long cores permeability saturation curve, includes the following steps:
(1) dry weight for measuring rock core measures the weight in wet base of the rock core to saturated water after the rock core vacuumizing, and then obtains institute
State the pore volume of rock core；
The length of the rock core is 20~30cm；
(2) constant speed displacement is carried out to the rock core using salt water, interval collects production fluid and measures conductivity value, when the output
When the conductivity value of liquid is no longer changed, stop injecting the salt water；Draw the conductivity value and the salt of the production fluid
Relation curve between the injection pore volume of water, and then judge the homogenieity of the rock core；
(3) rock core is placed vertically, from the top of the rock core inject oil and be saturated, from the bottom of the rock core connect liquid to
There is no aquatic products to go out, measure output liquid measure, calculates irreducible water saturation；
(4) from the bottom of the rock core, injection water carries out water drive oil, connects liquid at the top of the rock core, records in different time periods
Aqueous oil content and injection pressure, calculation of water gas relative permeability, and then obtain the permeability saturation curve of rock core.
2. measuring method according to claim 1, it is characterised in that: in step (2), inject the salt with constant rate
Water；
Using the conductivity value of the production fluid in DDS-11A digital display conductivity meter METHOD FOR CONTINUOUS DETERMINATION same time interval.
3. measuring method according to claim 1 or 2, it is characterised in that: in step (3), calculate the beam according to the following formula
Tie up water saturation:
Swi=(v ˊ × T-Vwater)/Voil；
In formula, VwaterIndicate the water of output, VoilIndicate the oil mass of output, unit is mL；
V ˊ indicates it is the oily flow velocity of injection, unit mL/min；
T indicates injection length, unit min.
4. measuring method according to any one of claim 1-3, it is characterised in that: in step (4), the water drive oil mistake
Cheng Zhong, at water breakthrough initial stage, interval encryption connects liquid, until no oil output, records the pressure difference during the water drive oil, calculate output
Moisture content and oil content in liquid, and using J.B.N method calculate the water phase relative permeability at each moment, oil relative permeability and
Rock sample exit-end water saturation.
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Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109632604A (en) * | 2019-01-04 | 2019-04-16 | 中国海洋石油集团有限公司 | A kind of pore scale is to rock core scale Relative Permeabilty From Polymer Displacement Experiment method of roughening |
| CN110130874A (en) * | 2019-06-03 | 2019-08-16 | 中国石油大学(北京) | The determination method and device that grease mutually seeps in Carbonate Reservoir water drive |
| CN111255444A (en) * | 2020-01-09 | 2020-06-09 | 中海石油(中国)有限公司 | Method for measuring relative permeability of oil and gas in stratum |
| CN112081588A (en) * | 2020-10-26 | 2020-12-15 | 西南石油大学 | Method for judging viscosity change of chemical system in relative permeability curve |
| CN112505298A (en) * | 2020-12-01 | 2021-03-16 | 西南石油大学 | In-situ test method for compact oil gas storage and production performance parameters |
| CN113588513A (en) * | 2021-07-19 | 2021-11-02 | 西南石油大学 | Method for evaluating influence of loose sandstone structure on phase permeation curve form |
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| CN105606509A (en) * | 2015-12-22 | 2016-05-25 | 中国石油大学(华东) | Measuring method of high-temperature oil-water relative permeability of heavy oil reservoir |
| CN106525690A (en) * | 2016-12-02 | 2017-03-22 | 中国石油天然气股份有限公司 | Method for measuring gas-water relative permeability curve by tight sandstone steady-state method |
| CN106525685A (en) * | 2016-10-28 | 2017-03-22 | 西南石油大学 | Method used for evaluating heterogeneous degree of rock core |
| CN108444884A (en) * | 2018-03-26 | 2018-08-24 | 中国石油化工股份有限公司 | Oil relative permeability curve characterizing method based on Harris models |
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| CN105606509A (en) * | 2015-12-22 | 2016-05-25 | 中国石油大学(华东) | Measuring method of high-temperature oil-water relative permeability of heavy oil reservoir |
| CN106525685A (en) * | 2016-10-28 | 2017-03-22 | 西南石油大学 | Method used for evaluating heterogeneous degree of rock core |
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Cited By (10)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109632604A (en) * | 2019-01-04 | 2019-04-16 | 中国海洋石油集团有限公司 | A kind of pore scale is to rock core scale Relative Permeabilty From Polymer Displacement Experiment method of roughening |
| CN109632604B (en) * | 2019-01-04 | 2021-06-15 | 中国海洋石油集团有限公司 | Method for coarsening relative permeability of polymer flooding from pore size to core size |
| CN110130874A (en) * | 2019-06-03 | 2019-08-16 | 中国石油大学(北京) | The determination method and device that grease mutually seeps in Carbonate Reservoir water drive |
| CN111255444A (en) * | 2020-01-09 | 2020-06-09 | 中海石油(中国)有限公司 | Method for measuring relative permeability of oil and gas in stratum |
| CN111255444B (en) * | 2020-01-09 | 2023-04-28 | 中海石油(中国)有限公司 | Stratum oil gas relative permeability determination method |
| CN112081588A (en) * | 2020-10-26 | 2020-12-15 | 西南石油大学 | Method for judging viscosity change of chemical system in relative permeability curve |
| CN112081588B (en) * | 2020-10-26 | 2022-02-15 | 西南石油大学 | Method for judging viscosity change of chemical system in relative permeability curve |
| CN112505298A (en) * | 2020-12-01 | 2021-03-16 | 西南石油大学 | In-situ test method for compact oil gas storage and production performance parameters |
| CN112505298B (en) * | 2020-12-01 | 2022-02-15 | 西南石油大学 | In-situ test method for compact oil gas storage and production performance parameters |
| CN113588513A (en) * | 2021-07-19 | 2021-11-02 | 西南石油大学 | Method for evaluating influence of loose sandstone structure on phase permeation curve form |
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