CN105116107A - CO under oil reservoir condition2Identification method for phase state in ultra-low permeability homogeneous core - Google Patents
CO under oil reservoir condition2Identification method for phase state in ultra-low permeability homogeneous core Download PDFInfo
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- CN105116107A CN105116107A CN201510462388.1A CN201510462388A CN105116107A CN 105116107 A CN105116107 A CN 105116107A CN 201510462388 A CN201510462388 A CN 201510462388A CN 105116107 A CN105116107 A CN 105116107A
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- 238000000034 method Methods 0.000 title claims abstract description 82
- 230000035699 permeability Effects 0.000 title claims abstract description 19
- 239000003921 oil Substances 0.000 claims abstract description 106
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 41
- 238000006073 displacement reaction Methods 0.000 claims abstract description 28
- 239000010779 crude oil Substances 0.000 claims abstract description 19
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 14
- 239000008398 formation water Substances 0.000 claims abstract description 5
- 239000007789 gas Substances 0.000 claims description 53
- 239000011435 rock Substances 0.000 claims description 53
- 239000012530 fluid Substances 0.000 claims description 37
- 238000002347 injection Methods 0.000 claims description 11
- 239000007924 injection Substances 0.000 claims description 11
- 238000003756 stirring Methods 0.000 claims description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 6
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 6
- 230000005514 two-phase flow Effects 0.000 claims description 4
- 238000004140 cleaning Methods 0.000 claims description 3
- 238000001035 drying Methods 0.000 claims description 3
- 229910052757 nitrogen Inorganic materials 0.000 claims description 3
- 239000003208 petroleum Substances 0.000 claims description 3
- 238000004088 simulation Methods 0.000 claims description 3
- 238000012546 transfer Methods 0.000 claims description 3
- 230000003068 static effect Effects 0.000 abstract description 6
- 238000013461 design Methods 0.000 abstract description 5
- 208000035126 Facies Diseases 0.000 description 5
- 239000007788 liquid Substances 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- 238000002156 mixing Methods 0.000 description 4
- 238000004364 calculation method Methods 0.000 description 3
- 238000011084 recovery Methods 0.000 description 3
- 238000010998 test method Methods 0.000 description 3
- 238000004458 analytical method Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000009792 diffusion process Methods 0.000 description 1
- 230000008034 disappearance Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000005431 greenhouse gas Substances 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000010561 standard procedure Methods 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
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Abstract
The invention provides CO under oil reservoir conditions2The invention relates to a method for identifying a phase state in an ultra-low permeability homogeneous core according to different pressures CO2Solubility in formation oil and core CO different modes2The method for judging CO by combining the gas-oil ratio at the outlet end in the flooding process2CO in oil displacement and gas-water alternative oil displacement process2State in oil. For a specific reservoir temperature, static data is obtained by measuring CO under different pressure conditions according to PVT2Solubility data in crude oil; and the dynamic data is gas-oil ratio data of the outlet end at different pressures in the process of core gas flooding or gas-water alternate flooding. According to the static and dynamic data comparison, analyzing CO in the displacement process2Crude oil and formation water conditions at formation conditions. Can be CO2The design of the field driving scheme provides certain guidance.
Description
Technical field
The present invention relates in oil-gas field development and improve recovery efficiency technique field, particularly CO under a kind of reservoir condition
2in extra-low permeability homogeneous rock core, phase sentences knowledge method.
Background technology
CO
2mainly there are gaseous state, four kinds of states such as overcritical, liquid and solid-state.When temperature higher than 31.1 DEG C, pressure higher than 7.38MPa time, CO
2enter critical conditions, in supercriticality, CO
2typical physical is: density is bordering on liquid, is gas hundred times; Viscosity is bordering on gas, compared with liquid, and little two orders of magnitude; Coefficient of diffusion, between gas and liquid, is about 1/100 of gas, and hundred times larger than liquid, thus has larger dissolving power.When temperature is lower than-78 DEG C, CO
2to exist in solid form.
CO
2the displacement of reservoir oil improves recovery ratio and technology of burying receives attention day by day as a kind of effective ways of greenhouse gases recycling, and this technology has a good application prospect in hyposmosis, extra-low permeability oil reservoirs exploitation.CO2 is dissolvable in water in crude oil and is mixed phase, is non-mixed phase if be not dissolved in crude oil; According to CO
2mixed phase can be arrived under formation conditions, CO with in-place oil
2technology of reservoir sweep is divided into again mixed phase to drive and non-phase-mixing driving two kinds.Compare non-phase-mixing driving, CO
2more high recovery rate can be obtained under mixed phase state, CO with in-place oil
2can mixed phase be the key condition carrying out reservoir selection with in-place oil.
CO under reservoir condition
2mainly divide two kinds with the state of in-place oil, one is CO
2be dissolved in oil, CO
2for discontinuous phase; Another kind is CO
2exist with the form of free gas, CO
2for continuous phase.Minimum miscibility pressure (MMP) is CO
2the minimum pressure of mixed phase is reached with in-place oil.Usually CO is judged with mean reservoir pressure and minimum miscibility pressure (MMP) relative size in oil reservoir development process
2whether-crude oil system reaches mixed phase under reservoir conditions.When mean reservoir pressure is greater than MMP, be judged to be CO
2mixed phase drives; Otherwise, be CO
2non-phase-mixing driving.Determine that the method for minimum miscibility pressure mainly contains experimental determination and theory calculate two kinds at present, wherein, laboratory determines that method comprises slim-tube test method, interfacial tension disappearance method, vapour density method and liter bubble instrument method; Theoretical calculation comprises experimental formula prediction and chart method, multiple-contact method, Method for Numerical, state equation computing method and anchor line (string) analytical calculations.In traditional laboratory determination method, the slim-tube test method that nineteen eighty-three Stalkup proposes is the method for determination minimum miscibility pressure internationally recognized and general at present, also always as the standard method measuring minimum miscibility pressure.But due to different times oil reservoir different parts CO in gas injection process
2state is change, supercritical CO under reservoir condition
2in crude oil, have good solubility property, MMP accurately can not judge CO
2cO in displacement process
2state changes.So adopt mean reservoir pressure value and MMP relative size can not truly reflect CO in oil reservoir
2state change in the earth formation.
Current judgement CO
2it is that relative size according to current mean reservoir pressure and minimum miscibility pressure judges that mixed phase drives with non-phase-mixing driving, it is mixed phase when reservoir pressure is greater than minimum miscibility pressure, otherwise be non-mixed phase, although the method can clearly judge mixed phase state qualitatively, but do not consider the change of true oil reservoir internal pressure, this determination methods be divided into two is too general, unclear to causing the process of result to be familiar with.In addition, utilize slim-tube test method determination minimum miscibility pressure length consuming time, workload large.
Summary of the invention
In order to overcome in existing method, MMP accurately can not judge CO
2cO in displacement process
2state changes and can not truly reflect CO in oil reservoir
2the problem of state change in the earth formation, the invention provides CO under a kind of reservoir condition
2in extra-low permeability homogeneous rock core phase sentence knowledge method, of the present invention is according to different pressures CO
2solubleness (static data) in formation oil and rock core different modes CO
2the method that the output gas oil ratio (dynamic data) of driving process middle outlet end combines, judges CO
2drive and CO in Water Alternate Gas displacement of reservoir oil process
2state in oil.Pass through CO
2the qualitative judgement of state can the distribution of each facies tract and size in rational judgment rock core, is more deep understanding CO
2the characteristic sum different modes CO of oil displacement process and displacement
2oil-displacement mechanism provides a kind of new method, can be CO
2the design of driving on-the-spot scheme provides certain guidance.
The technical solution used in the present invention is:
CO under a kind of reservoir condition
2in extra-low permeability homogeneous rock core phase sentence knowledge method, concrete steps are:
1) CO under acquisition different pressures
2solubleness in formation oil
A, join reservoir fluid: with sherwood oil cleaning sample still three times, vacuumize 2 hours; Crude oil, after 6 hours, is pressed in sample still with manual pump by sample still and crude oil sample still constant temperature at 50 DEG C;
B, join specify CO
2the reservoir fluid of concentration: first by pipeline and PVT instrument petroleum ether, and be evacuated to below 200mmHg after drying up with nitrogen, then by CO
2gas, after the boosting of oil-free lubricatoin supercharger, opens the valve of PVT instrument, press-in CO
2gas; Constant temperature is after 4 ~ 5 hours, according to volume, the CO of sample still
2cO in pressure and temperature computation PVT instrument
2amount, adjustment pressure is to required CO
2amount; Reservoir fluid in sample still is pressed into single-phase and constant temperature after 4 hours simultaneously, reservoir fluid is pressed in PVT instrument;
C, measure join the PVT character of reservoir fluid: reservoir fluid in PVT instrument is pressed into single-phase after, stirring shakes up, and stablizes 30 minutes; Then pressure from high to low, the reservoir fluid PVT data under 1-2MPa measures different pressures respectively; Can draw the bubble point pressure of reservoir fluid according to the catastrophe point of system volume, the CO2 concentration obtained corresponding to bubble point pressure is CO
2solubleness;
2) rock core CO is obtained
2the output gas oil ratio of expelling water process middle outlet end
Choose rock core, length is 30cm, and diameter is 2.5cm, and rock core perm-plug method is 1.707mD, and factor of porosity is 11.4%, and experimental temperature is 50 DEG C, experimental simulation oil, and viscosity is 1.5mPa*s, water, and salinity is 60000mg/L, end back pressure 10.0MPa;
First dry rock sample, measure permeability and factor of porosity, set up irreducible water saturation, carry out water displacing oil with constant flow velocity 0.1ml/min, after moisture more than 98.0%, stop water filling; CO is carried out with constant flow velocity 0.1ml/min
2expelling water, until the complete aerogenesis of endpiece; In experimentation, record injection pressure, water, produce oil and aerogenesis volume are produced in outlet;
3) judgement of CO2 state in crude oil in rock core displacement process
In the three-phase flow stage, CO
2that the form be dissolved in oil exists, CO
2solubleness in oil is greater than 100, and output gas oil ratio is 0-10.0, and the pressure in rock core is 15.5-16.1mpa;
In the oil-gas two-phase flow stage, CO
2be dissolved in oil, CO
2solubleness in oil is 120-140, and output gas oil ratio is 10-140, and the pressure of rock core injection side is 16.1-16.7MPa; CO
2be free gas, output gas oil ratio is 140-1436.
In step 1), all to carry out under single-phase condition from during sample still transfer sample at every turn.
When surveying reservoir fluid PVT data matter in step 1), often measure spot pressure data and all will stir, shake up 30 minutes, leave standstill 30 minutes.
When surveying the reservoir fluid PVT data under different pressures in step 1), survey reservoir fluid PVT data every 2MPa.
Step 2) in experimental water be corresponding oil field simulated formation water.
Beneficial effect of the present invention is:
Of the present invention is that a kind of method utilizing quiet dynamic data to combine judges CO in rock core different modes gas drive process
2state in oil.This invention can be used for judging whole CO
2cO in oil displacement process
2the change of state in oil, having taken into account result and the process causing this result, is deep understanding different modes CO
2the process of the displacement of reservoir oil and mechanism provide a kind of new method, are CO
2the design of driving on-the-spot scheme provides certain guidance.
Be further detailed below with reference to accompanying drawing.
Accompanying drawing explanation
Fig. 1, the crude oil CO 50 DEG C time under different pressures
2dissolubility data figure.
Fig. 2, CO
2drive in process and produce water, oil, gas schematic diagram.
Fig. 3, CO
2drive injection pressure and output gas oil ratio variation diagram in process.
Fig. 4, CO
2drive rock core facies tract distribution situation in process.
Embodiment
Embodiment 1:
In order to overcome in existing method, MMP accurately can not judge CO
2cO in displacement process
2state changes and can not truly reflect CO in oil reservoir
2the problem of state change in the earth formation, the invention provides CO under a kind of reservoir condition
2in extra-low permeability homogeneous rock core phase sentence knowledge method, of the present invention is according to different pressures CO
2solubleness (static data) in formation oil and rock core different modes CO
2the method that the output gas oil ratio (dynamic data) of driving process middle outlet end combines, judges CO
2drive and CO in Water Alternate Gas displacement of reservoir oil process
2state in oil.Pass through CO
2the qualitative judgement of state can the distribution of each facies tract and size in rational judgment rock core, is more deep understanding CO
2the characteristic sum different modes CO of oil displacement process and displacement
2oil-displacement mechanism provides a kind of new method, can be CO
2the design of driving on-the-spot scheme provides certain guidance.
CO under a kind of reservoir condition
2in extra-low permeability homogeneous rock core phase sentence knowledge method, concrete steps are:
2) CO under acquisition different pressures
2solubleness in formation oil
A, join reservoir fluid: with sherwood oil cleaning sample still three times, vacuumize 2 hours; Crude oil, after 6 hours, is pressed in sample still with manual pump by sample still and crude oil sample still constant temperature at 50 DEG C;
B, join specify CO
2the reservoir fluid of concentration: first by pipeline and PVT instrument petroleum ether, and be evacuated to below 200mmHg after drying up with nitrogen, then by CO
2gas, after the boosting of oil-free lubricatoin supercharger, opens the valve of PVT instrument, press-in CO
2gas; Constant temperature is after 4 ~ 5 hours, according to volume, the CO of sample still
2cO in pressure and temperature computation PVT instrument
2amount, adjustment pressure is to required CO
2amount; Reservoir fluid in sample still is pressed into single-phase and constant temperature after 4 hours simultaneously, reservoir fluid is pressed in PVT instrument;
C, measure join the PVT character of reservoir fluid: reservoir fluid in PVT instrument is pressed into single-phase after, stirring shakes up, and stablizes 30 minutes; Then pressure from high to low, the reservoir fluid PVT data under 1-2MPa measures different pressures respectively; Can draw the bubble point pressure of reservoir fluid according to the catastrophe point of system volume, the CO2 concentration obtained corresponding to bubble point pressure is CO
2solubleness;
2) rock core CO is obtained
2the output gas oil ratio of expelling water process middle outlet end
Choose rock core, length is 30cm, and diameter is 2.5cm, and rock core perm-plug method is 1.707mD, and factor of porosity is 11.4%, and experimental temperature is 50 DEG C, experimental simulation oil, and viscosity is 1.5mPa*s, water, and salinity is 60000mg/L, end back pressure 10.0MPa;
First dry rock sample, measure permeability and factor of porosity, set up irreducible water saturation, carry out water displacing oil with constant flow velocity 0.1ml/min, after moisture more than 98.0%, stop water filling; CO is carried out with constant flow velocity 0.1ml/min
2expelling water, until the complete aerogenesis of endpiece; In experimentation, record injection pressure, water, produce oil and aerogenesis volume are produced in outlet;
3) judgement of CO2 state in crude oil in rock core displacement process
In the three-phase flow stage, CO
2that the form be dissolved in oil exists, CO
2solubleness in oil is greater than 100, and output gas oil ratio is 0-10.0, and the pressure in rock core is 15.5-16.1mpa;
In the oil-gas two-phase flow stage, CO
2be dissolved in oil, CO
2solubleness in oil is 120-140, and output gas oil ratio is 10-140, and the pressure of rock core injection side is 16.1-16.7MPa; CO
2be free gas, output gas oil ratio is 140-1436.
In the present invention, reservoir fluid in PVT instrument is pressed into single-phase after, stirring shakes up, and stablizes 30 minutes.Then pressure from high to low, the reservoir fluid PVT data under 1-2MPa measures different pressures respectively.Often measure spot pressure data all will stir, shake up 30 minutes, leave standstill 30 minutes.Can draw the bubble point pressure of reservoir fluid according to the catastrophe point of system volume, the CO2 concentration corresponding to this bubble point pressure is CO
2solubleness.
Solubility test as shown in Figure 1.
Rock core displacement dynamic data obtains, choose the Berea core of Unite States Standard (USS), length is 30cm, and diameter is 2.5cm, rock core perm-plug method is 1.707mD, factor of porosity is 11.4%, and experimental temperature is 50 DEG C, and experiment oil is long certain oil field simulated oil of celebrating, viscosity is 1.5mPa*s, experimental water is corresponding oil field simulated formation water, and salinity is 60000mg/L, end back pressure 10.0MPa.
Experimentation is as follows: according to SY/T5336-2006 " core analysis method ", dries rock sample, measures permeability and factor of porosity; According to SY/T5354-2007 " in rock, two-phase fluid relative permeability measures " 3.4 pairs of saturated local waters of rock sample wherein, wherein 6.2.4 sets up irreducible water saturation; Carry out water displacing oil with constant flow velocity 0.1ml/min, after moisture more than 98.0%, stop water filling; CO is carried out with constant flow velocity 0.1ml/min
2drive, until the complete aerogenesis of endpiece; In experimentation, record injection pressure, water, produce oil and aerogenesis volume are produced in outlet.
The judgement of CO2 state in crude oil in rock core displacement process
If Fig. 2 is rock core CO
2drive the product water in process, produce oil and aerogenesis volume, Fig. 3 is pressure in injection process and output gas oil ratio data.Produce the time point of water, aerogenesis and produce oil according to outlet, the flowing in rock core can be divided into different types.
Fig. 4 is CO
2drive rock core facies tract distribution situation figure in process, in the three-phase flow stage, the pressure in rock core is 15.5-16.1mpa, and output gas oil ratio is now 0-10.0, and the solubleness in this pressure limit in oil is greater than 100, thinks CO now
2that the form be dissolved in oil exists; In the oil-gas two-phase flow stage, the pressure of rock core injection side is 16.1-16.7MPa, and now that output gas oil ratio is 10-1436, and in this pressure limit, solubleness is 120-140, can judge when output gas oil ratio is at 10-140, CO
2be dissolved in oil, during 140-1436, CO
2it is free gas.
Embodiment 2:
On basis based on embodiment 1, in the present embodiment step 1), all to carry out under single-phase condition from during sample still transfer sample at every turn.
When surveying the reservoir fluid PVT data under different pressures in step 1), survey reservoir fluid PVT data every 2MPa.When surveying reservoir fluid PVT data matter in step 1), often measure spot pressure data and all will stir, shake up 30 minutes, leave standstill 30 minutes.
Like this can be stable and clear and definite record bubble point pressure.
Step 2) in experimental water be corresponding oil field simulated formation water.Use the underground water of described simulated oil, so just can ensure the unicity of variable.
Of the present invention is according to different pressures CO
2solubleness (static data) in formation oil and rock core CO
2the method that the output gas oil ratio (performance analysis) of driving different pressures moment endpiece in process combines, judges CO
2cO in oil displacement process
2state in profit.During maximum dissolved gas when output gas oil ratio is less than this pressure, think CO
2existing with the form being dissolved in oil, is mixed phase state; Otherwise, think CO
2existing with the form of free gas, is non-mixed phase state.To a certain specific reservoir temperature, static data records CO under different pressures condition according to PVT
2dissolubility data in crude oil; The output gas oil ratio data of endpiece when dynamic data is different pressures in rock core gas drive (or Water alternating gas) process.Contrast according to quiet dynamic data, analyze CO in displacement process
2state in crude oil under formation conditions and local water.
Of the present invention is according to different pressures CO
2solubleness in formation oil and rock core different modes CO
2the method that the output gas oil ratio of driving process middle outlet end combines, judges CO
2drive and CO in Water Alternate Gas displacement of reservoir oil process
2state in oil.Pass through CO
2the qualitative judgement of state can the distribution of each facies tract and size in rational judgment rock core, is more deep understanding CO
2the characteristic sum different modes CO of oil displacement process and displacement
2oil-displacement mechanism provides a kind of new method, can be CO
2the design of driving on-the-spot scheme provides certain guidance.
Claims (5)
1. CO under a reservoir condition
2in extra-low permeability homogeneous rock core phase sentence knowledge method, it is characterized in that: concrete steps are:
1) CO under acquisition different pressures
2solubleness in formation oil
A, join reservoir fluid: with sherwood oil cleaning sample still three times, vacuumize 2 hours; Crude oil, after 6 hours, is pressed in sample still with manual pump by sample still and crude oil sample still constant temperature at 50 DEG C;
B, join specify CO
2the reservoir fluid of concentration: first by pipeline and PVT instrument petroleum ether, and be evacuated to below 200mmHg after drying up with nitrogen, then by CO
2gas, after the boosting of oil-free lubricatoin supercharger, opens the valve of PVT instrument, press-in CO
2gas; Constant temperature is after 4 ~ 5 hours, according to volume, the CO of sample still
2cO in pressure and temperature computation PVT instrument
2amount, adjustment pressure is to required CO
2amount; Reservoir fluid in sample still is pressed into single-phase and constant temperature after 4 hours simultaneously, reservoir fluid is pressed in PVT instrument;
C, measure join the PVT character of reservoir fluid: reservoir fluid in PVT instrument is pressed into single-phase after, stirring shakes up, and stablizes 30 minutes; Then pressure from high to low, the reservoir fluid PVT data under 1-2MPa measures different pressures respectively; Can draw the bubble point pressure of reservoir fluid according to the catastrophe point of system volume, the CO2 concentration obtained corresponding to bubble point pressure is CO
2solubleness;
2) rock core CO is obtained
2the output gas oil ratio of expelling water process middle outlet end
Choose rock core, length is 30cm, and diameter is 2.5cm, and rock core perm-plug method is 1.707mD, and factor of porosity is 11.4%, and experimental temperature is 50 DEG C, experimental simulation oil, and viscosity is 1.5mPa*s, water, and salinity is 60000mg/L, end back pressure 10.0MPa;
First dry rock sample, measure permeability and factor of porosity, set up irreducible water saturation, carry out water displacing oil with constant flow velocity 0.1ml/min, after moisture more than 98.0%, stop water filling; CO is carried out with constant flow velocity 0.1ml/min
2expelling water, until the complete aerogenesis of endpiece; In experimentation, record injection pressure, water, produce oil and aerogenesis volume are produced in outlet;
3) judgement of CO2 state in crude oil in rock core displacement process
In the three-phase flow stage, CO
2that the form be dissolved in oil exists, CO
2solubleness in oil is greater than 100, and output gas oil ratio is 0-10.0, and the pressure in rock core is 15.5-16.1mpa;
In the oil-gas two-phase flow stage, CO
2be dissolved in oil, CO
2solubleness in oil is 120-140, and output gas oil ratio is 10-140, and the pressure of rock core injection side is 16.1-16.7MPa; CO
2be free gas, output gas oil ratio is 140-1436.
2. CO under a kind of reservoir condition according to claim 1
2in extra-low permeability homogeneous rock core phase sentence knowledge method, it is characterized in that: in step 1), all will carry out under single-phase condition from during sample still transfer sample at every turn.
3. CO under a kind of reservoir condition according to claim 1
2in extra-low permeability homogeneous rock core phase sentence knowledge method, it is characterized in that: when surveying reservoir fluid PVT data matter in step 1), often measure spot pressure data all to stir, shake up 30 minutes, leave standstill 30 minutes.
4. CO under a kind of reservoir condition according to claim 1
2in extra-low permeability homogeneous rock core phase sentence knowledge method, it is characterized in that: when surveying the reservoir fluid PVT data under different pressures in step 1), survey reservoir fluid PVT data every 2MPa.
5. CO under a kind of reservoir condition according to claim 1
2in extra-low permeability homogeneous rock core phase sentence knowledge method, it is characterized in that: step 2) in experimental water be corresponding oil field simulated formation water.
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| CN113969784A (en) * | 2021-11-05 | 2022-01-25 | 西南石油大学 | Method for distinguishing miscible phase of injected hydrocarbon gas flooding in mine field |
| CN117990891A (en) * | 2024-02-28 | 2024-05-07 | 西南石油大学 | Device and method for measuring solubility of carbon dioxide in crude oil or water in stratum under condition of porous medium |
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