CN113431537B - Unsteady variable-flow-rate large-scale rock core water flooding gas relative permeability testing method - Google Patents
Unsteady variable-flow-rate large-scale rock core water flooding gas relative permeability testing method Download PDFInfo
- Publication number
- CN113431537B CN113431537B CN202110732812.5A CN202110732812A CN113431537B CN 113431537 B CN113431537 B CN 113431537B CN 202110732812 A CN202110732812 A CN 202110732812A CN 113431537 B CN113431537 B CN 113431537B
- Authority
- CN
- China
- Prior art keywords
- water
- gas
- core
- flooding
- pressure
- 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.)
- Active
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 171
- 230000035699 permeability Effects 0.000 title claims abstract description 74
- 239000011435 rock Substances 0.000 title claims abstract description 16
- 238000012360 testing method Methods 0.000 title claims abstract description 15
- 238000002474 experimental method Methods 0.000 claims abstract description 73
- 238000000034 method Methods 0.000 claims abstract description 50
- 238000011160 research Methods 0.000 claims abstract description 9
- 229910052500 inorganic mineral Inorganic materials 0.000 claims abstract description 7
- 239000011707 mineral Substances 0.000 claims abstract description 7
- 239000000203 mixture Substances 0.000 claims abstract description 7
- 238000005303 weighing Methods 0.000 claims abstract description 7
- 230000002194 synthesizing effect Effects 0.000 claims abstract 2
- 239000007789 gas Substances 0.000 claims description 196
- 239000012071 phase Substances 0.000 claims description 37
- 238000002347 injection Methods 0.000 claims description 35
- 239000007924 injection Substances 0.000 claims description 35
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 32
- 230000008569 process Effects 0.000 claims description 30
- 238000005481 NMR spectroscopy Methods 0.000 claims description 26
- 239000011521 glass Substances 0.000 claims description 23
- 239000012530 fluid Substances 0.000 claims description 21
- 238000001035 drying Methods 0.000 claims description 19
- 229910052757 nitrogen Inorganic materials 0.000 claims description 16
- 238000001228 spectrum Methods 0.000 claims description 16
- 230000008859 change Effects 0.000 claims description 15
- 238000009826 distribution Methods 0.000 claims description 15
- 239000000243 solution Substances 0.000 claims description 15
- 238000006073 displacement reaction Methods 0.000 claims description 13
- 238000012544 monitoring process Methods 0.000 claims description 13
- 239000011148 porous material Substances 0.000 claims description 13
- 238000004364 calculation method Methods 0.000 claims description 12
- 229920006395 saturated elastomer Polymers 0.000 claims description 9
- 230000001186 cumulative effect Effects 0.000 claims description 8
- 239000008346 aqueous phase Substances 0.000 claims description 7
- 238000005259 measurement Methods 0.000 claims description 7
- 239000008398 formation water Substances 0.000 claims description 5
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims description 3
- 238000010521 absorption reaction Methods 0.000 claims description 3
- 230000009471 action Effects 0.000 claims description 3
- 238000012937 correction Methods 0.000 claims description 3
- 238000004134 energy conservation Methods 0.000 claims description 3
- 239000007788 liquid Substances 0.000 claims description 3
- 230000001105 regulatory effect Effects 0.000 claims 1
- 238000009738 saturating Methods 0.000 claims 1
- 238000004519 manufacturing process Methods 0.000 description 17
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 14
- 239000011575 calcium Substances 0.000 description 11
- 238000011161 development Methods 0.000 description 9
- 239000003345 natural gas Substances 0.000 description 7
- 230000009545 invasion Effects 0.000 description 6
- 230000008901 benefit Effects 0.000 description 4
- 238000010998 test method Methods 0.000 description 3
- 230000009286 beneficial effect Effects 0.000 description 2
- 238000003763 carbonization Methods 0.000 description 2
- 230000007547 defect Effects 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 238000002441 X-ray diffraction Methods 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000000691 measurement method Methods 0.000 description 1
- 238000013508 migration Methods 0.000 description 1
- 230000005012 migration Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000005380 natural gas recovery Methods 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 230000003595 spectral effect Effects 0.000 description 1
- 238000007619 statistical method Methods 0.000 description 1
- 230000005514 two-phase flow Effects 0.000 description 1
- 238000012795 verification Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/02—Valve arrangements for boreholes or wells in well heads
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
- G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
- G06Q50/02—Agriculture; Fishing; Mining
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A90/00—Technologies having an indirect contribution to adaptation to climate change
- Y02A90/30—Assessment of water resources
Abstract
The application belongs to the technical field of water-flooding gas reservoir exploitation, and particularly relates to a method for testing the relative permeability of water-flooding gas of a unsteady variable-flow-rate large-scale rock core, which comprises the following steps: after coring from a research area, measuring the porosity phi and the permeability K of a cored sample, determining the range of the porosity phi and the permeability K by combining a logging curve of the research area, performing X diffraction on the cored sample to obtain mineral composition, synthesizing an artificial large-scale full-diameter core within the range of the corresponding porosity phi and the permeability K according to the mineral composition of the cored sample, putting the artificial large-scale full-diameter core into an oven to dry for 48 hours, taking out, measuring the diameter D and the length L of the core according to industry standards, calculating the sectional area A, measuring the porosity phi and the permeability K, weighing the dry weight M1 under the atmospheric pressure Pa, and measuring the air-driving water and the air-driving experiment simultaneously by two six-way valves.
Description
Technical Field
The application relates to the technical field of water-flooding gas reservoir exploitation, in particular to a method for testing the relative permeability of water-flooding gas of a unsteady variable-flow-rate large-scale rock core.
Background
World energy optimization structures require energy to gradually develop to low and even no carbonization. Natural gas is used as a low-carbonization energy source, has high thermal efficiency and good environmental benefit, and occupies a significant position in the current energy structure. According to the world energy statistical analysis in 2020, the natural gas accounts for 24.2% of the total energy in a world oil-gas primary energy consumption structure, and the history is new and high. From the form of our country, the country has improved the development and utilization of natural gas to a very important location. Therefore, increasing the yield of natural gas will help the national economy of China to increasingly demand natural gas. Domestic water flooding gas reservoirs have a large specific gravity in the gas reservoirs which are put into development, and are mainly distributed in Sichuan gas fields, south-sea gas fields and the like. The water-flooding gas reservoir does not produce water in the initial stage of development, and along with the reduction of production pressure, the invasion of side water is a main reason for the gas-water two-phase flow in the later stage of development of the water-flooding gas reservoir. The gas-water two-phase seepage theory belongs to multiphase seepage theory research, most multiphase seepage theory mainly focuses on oil-water two-phase seepage, oil-gas two-phase seepage and oil-gas-water three-phase seepage, and research on the gas-water two-phase seepage process is relatively less. For porous loose sandstone water-flooding gas reservoirs with strong heterogeneity, the development process mainly takes a water-flooding gas seepage form as a main principle. In the development process of the water-flooding gas reservoir, the two-phase seepage process is complex, and in the development process of the gas reservoir, the side water invades into the gas zone to form water-flooding gas two-phase seepage, and as the pressure of the produced stratum is reduced, the closed gas volume expands to form gas-flooding water two-phase seepage in the gas reservoir. Therefore, the water-flooding gas reservoir has two seepage modes of water-flooding gas and gas-flooding water in the seepage process. The gas-driven water and water-driven gas seepage processes are different, the experimental measurement method and the relative permeability curve are also different, and the obtained residual gas saturation is greatly different. Obviously, the gas-drive water relative permeability experimental measurement result used in the mine field experiment at present is used for obtaining the water-drive gas reservoir residual gas distribution and the actual water-drive gas reservoir residual gas distribution, so that the efficient exploitation of the actual water-drive gas reservoir residual gas is difficult to guide.
The prior art can obtain a water-gas relative permeability curve, but due to the special reservoir forming conditions and exploitation requirements of the water-flooding gas reservoir, certain defects exist when the methods are applied to the water-flooding gas reservoir:
(1) The water-flooding gas reservoir has stronger heterogeneity, and the absolute permeability of the reservoir varies from a few millidarcies to hundreds of millidarcies. The pore throat distribution is complex, the direct acquisition of the water-gas relative permeability curve by the conventional experiment is difficult, and the price is high.
(2) Most of the water-flooding gas reservoirs are rich in more active side bottom water, and the seepage rules of the water-flooding gas reservoirs are very complex due to the invasion of the side bottom water. The calculation formula of the relative permeability of the gas phase and the water phase of the conventional gas reservoir and the calculation formula of the water saturation can not meet the actual production requirements of the water flooding gas reservoir.
(3) At present, most of gas reservoirs use an experimental method of unsteady gas flooding to obtain a gas-water relative permeability curve, and the method overcomes the defects of time consuming of a steady state method, but because the permeability of most of water flooding gas reservoirs is high, the gas-water relative permeability curve obtained by the experimental method of gas flooding is wide in two-phase co-permeation area and low in residual gas saturation. If the residual gas distribution calculated by the relative permeability curve obtained by gas flooding has great deviation from the actual residual gas distribution of the gas reservoir, the prediction is inaccurate, and the recovery ratio of the residual gas is not beneficial to improvement.
(4) In the water flooding gas reservoir, particles on the surface of a reservoir fall off and migrate to cause the change of gas-water relative permeability. The current experimental methods cannot be measured and calibrated.
(5) The gas content in the conventional standard core (5 cm x 2.5 cm) is low, and the pressure difference between the inlet end and the outlet end causes the gas volume to expand. It is difficult to accurately measure the cumulative gas production in conventional standard cores using water-flooding experimental methods. The measured relative permeability curve is inaccurate.
(6) During the experiment, the dead pore volume in the pipeline, the clamp and the metering device has a great influence on the acquisition of the relative permeability data of the gas phase and the water phase.
(7) The method for indirectly solving the relative permeability of other gas-water phases, such as production data calculation, capillary pressure calculation and the like, has large calculated amount and high cost.
Therefore, accurately obtaining the residual gas distribution of the water-flooding gas reservoir and measuring and calibrating the gas-water two-phase seepage law is always the leading-edge subject of the water-flooding gas reservoir seepage theory research and is also a key technology for improving the recovery ratio of the water-flooding gas reservoir to be solved urgently. In order to better study the development rule of the water-flooding gas reservoir, the influence of factors such as solid particle migration, water invasion speed and the like on the relative permeability of water and gas phases in the water invasion process must be taken into account. Because the pore range of the conventional standard core (2.5 cm x 5 cm) is too small, the gas content is small and the cumulative gas production cannot be accurately measured. Therefore, this patent uses artificial large-scale rock core (7 cm. Times.10cm), and the rock core porosity is about 20%, guarantees that the gas volume in the rock core is enough to be accurately measured at the exit end. In addition, the U-shaped pipe principle is utilized in the patent, and the accumulated gas production and the accumulated water production of the outlet end which are increased along with time are measured by adopting a drainage gas production method. And comparing the experimental measurement result with the nuclear magnetic resonance T2 spectrum result, and reducing experimental error so that the experimental result can be more in line with an actual gas reservoir. Finally, during experimental data processing, a non-steady state JBN fitting mode is adopted to perform data fitting of water vapor permeation, and due to the compressibility of the gas, we have to solve the volume increment of the gas under the average pressure. In calculating water saturation using large scale core experiments, the dead pore volume is a non-negligible amount. In the experimental process and data processing, dead pore volumes should be manually removed to avoid shifting the relative permeability curves.
Disclosure of Invention
This section is intended to outline some aspects of embodiments of the application and to briefly introduce some preferred embodiments. Some simplifications or omissions may be made in this section as well as in the description of the application and in the title of the application, which may not be used to limit the scope of the application.
The application is provided in view of the problems existing in the existing gas-driven water relative permeability test method.
Therefore, the application aims to provide the unsteady variable-flow-rate large-scale core water-flooding gas relative permeability test method, which can simultaneously measure gas-flooding water and water-flooding gas experiments by only two six-way valves, and has the advantages of simple operation, low cost, multiple realized functions and high accuracy.
In order to solve the technical problems, according to one aspect of the present application, the following technical solutions are provided:
a method for testing the relative permeability of water-flooding gas of a unsteady variable-flow-rate large-scale rock core comprises the following steps:
step one: measuring the porosity phi and the permeability K of the core sample after coring from the research area, determining the range of the porosity phi and the permeability K by combining the logging curve of the research area, and carrying out X-ray diffraction on the core sample to obtain the oreSynthesizing an artificial large-scale full-diameter core with corresponding porosity phi and permeability K according to mineral composition of a core sample, putting the artificial large-scale full-diameter core into a baking oven, baking for 48 hours, taking out, measuring the diameter D and the length L of the core according to industry standards, calculating the sectional area A, measuring the dry weight M1 of the core under the atmospheric pressure Pa, putting the core sample after dry weight weighing into a vacuum pump, vacuumizing, pressurizing, simulating formation water KCL solution, weighing wet weight M2, and putting the core sample after KCL solution saturation into nuclear magnetic resonance T 2 In the monitoring system 14, T in the fully saturated state is scanned 2 A spectrogram;
step two: the core after saturated KCL solution is put into a large-scale full-diameter core holder 6, and is connected according to the connection mode shown in figure 1, and firstly, a gas flooding experiment is carried out to establish the irreducible water saturation, and the specific method is as follows: the valve of the six-way valve at the left end of the core holder, which is connected with the nitrogen bottle 1, is opened, the valve of the ISCO fluid injection pump 2, which is connected with the dry bottle 10, is closed, the valve of the glass tube with scales 11, which is connected with the right end of the six-way valve, is opened, and the line shown in the figure 1 is a gas-driven water experiment flow;
step three: establishing irreducible water saturation; the confining pressure is added to the large-scale full-diameter rock core holder 6 by a high-precision confining pressure pump until the confining pressure reaches 15MPa, and then a confining pressure pump valve is closed, so that the confining pressure in the rock core holder 6 is kept unchanged at 15MPa all the time; opening a nitrogen bottle 1, and performing a gas flooding experiment according to the reference displacement pressure difference calculated by the formula 1 through a pressure reducing valve; the accumulated time is measured by a stopwatch during the experiment, the pressure sensor 4 measures the displacement pressure difference during the experiment, the electronic balance 9 measures the weight M3 of the absorption solution in the drying bottle 4, and the gas flow measuring device 13 measures the amount of the extracted gas; stopping air supply until the weight of the electronic balance 9 is not changed any more or the injected gas amount is more than 30 times of the pore volume of the core; the core weight M3 under the state of water constraint is weighed, and the pore volume V under the state of water constraint is calculated Φ ；
V Φ ＝ALΦ-(M3-M1)*μ w
Step four: placing the core in the bound water state into a nuclear magnetic resonance T2 spectrum monitoring system 14, and measuring the distribution of the bound water in the core; carrying out water flooding experiments under the action of different capillary numbers on the core in the water-bound state; in the water flooding experiment, a valve connected with an ISCO fluid injection pump 2 is opened by a six-way valve at the left end of a large-scale full-diameter core holder 6, and a valve connected with a nitrogen bottle 1 is closed; the right end of the large-scale full-diameter core holder 6 is closed to connect a valve of the drying bottle 10, and the valve of the glass tube 11 with scales is opened; the ISCO fluid injection pump 2 was adjusted so that the injection flow rates were respectively selected to be 0.5ml/min,1.5ml/min,2.5ml/min; calculating the number of injected capillary tubes by a capillary tube number calculation formula Ca= (v. Mu.w)/sigma. Gw; recording the accumulated time Deltat by using a stopwatch, metering the accumulated gas yield DeltaG increased along with time by using the change of the water level on the glass tube 11 with scales, reading the displacement pressure difference Deltap changed along with time by using the pressure sensor 4 connected with the left six-way valve 14, and reading the accumulated water yield DeltaW increased along with time by using the electronic balance 9 under the beaker 12;
the method comprises the steps of determining the water saturation, the relative water phase permeability and the relative gas phase permeability in the water flooding process according to a Darcy formula and an energy conservation law;
water-flooding gas saturation:
water flooding gas water saturation S w ＝100-S g
Relative permeability of aqueous phase:
gas phase relative permeability:
wherein:(As the gas has compressibility, the volume of the gas changes during the water flooding experiment, and the ΔG' obtained here refers to the increment of the volume of the gas at the average pressure, which isCorrection value), deducing and obtaining water saturation S of water flooding experiment o Relative permeability of aqueous phase K rw And gas phase relative permeability Kr g A calculation formula; the change of the gas volume along with the pressure difference is considered in a gas phase relative permeability formula, and the cumulative gas yield under the average pressure of delta G' is solved;
step five: in the water flooding experiment process, proper time is selected for nuclear magnetic resonance T 2 Spectrum measurement to obtain a cluster of distribution rules of injected water in the core along with the increase of time according to nuclear magnetic resonance T 2 And (3) calculating the residual gas saturation by using the spectrogram, and comparing and correcting the residual gas saturation obtained by using the nuclear magnetic resonance T2 spectrum with a residual gas saturation value obtained by using a water flooding gas experiment to obtain an error range of the experiment. And solving a correction coefficient epsilon in a water-flooding experiment water-gas relative permeability calculation formula.
As a preferable scheme of the unsteady state variable flow rate large-scale rock core water-flooding gas relative permeability testing method, the application comprises the following steps: adopts a water flooding experimental device and combines nuclear magnetic resonance T 2 The device is mainly completed by the following four systems including an energy supply system, an experimental test system, an experimental metering system and a nuclear magnetic resonance T 2 A spectrum monitoring system; the energy supply system comprises a nitrogen cylinder 1, an ISCO fluid injection pump 2, an intermediate container 3 for storing formation water, a pressure sensor 4 and a pressure reducing valve 5; the experimental test system comprises a large-scale full-diameter core holder 6, a high-precision confining pressure pump 7 and a pressure gauge 8; the experimental test system comprises an electronic balance 9, a drying bottle 10, a graduated glass tube 11, a beaker 12 and a gas flow metering device 13; nuclear magnetic resonance T 2 A spectrum monitoring system 14; loading a saturated water core into a large-scale full-diameter core holder 6, pressurizing the confining pressure to 15MPa by using a high-precision confining pressure pump 7, and closing the confining pressure pump to ensure that the pressure in the large-scale full-diameter confining pressure pump is kept unchanged at 15MPa in the experimental process; the left end of the large-scale full-diameter core holder 6 is connected with a six-way valve 14, one port of the six-way valve 14 is connected with a nitrogen cylinder 1 through a pressure reducing valve 5, the other port is connected with an ISCO fluid injection pump 2 through a pressure gauge 8 and an intermediate container 3, and the intermediate container 3 is connected with the ISCO fluid injection pump 2The simulated formation water in the (a) is injected into the core holder in a constant flow or constant pressure mode; the six-way valve is also provided with a pressure sensor 4, and the pressure change of the injected gas or the injected liquid can be accurately monitored through the pressure sensor; the other end of the large-scale full-diameter core holder 6 is also connected with a six-way valve 14, one port of the six-way valve 14 firstly passes through a drying bottle (filled with anhydrous calcium chloride) 10, the drying bottle is placed on an electronic balance 9, and the water quantity entering the drying bottle is measured through the electronic balance; the dried gas enters a gas flow metering device 13 for gas metering; the port is designed with less water because of more gas and less water in the air-driven water experiment process; when the gas-flooding experiment is carried out, the port is opened, and when the water-flooding experiment is carried out, the port is closed; the other port of the six-way valve 14 is connected to the graduated glass tube 11 through a pipeline, water is filled in the graduated glass tube 11, and the graduated glass tube 11 is inversely inserted into the beaker 12 for filling water and fixed; an electronic balance 9 is arranged at the lower end of the beaker 12; when the water flooding experiment is carried out, the air quantity is small and the water quantity is large, and the trace air quantity can be accurately measured by adopting the method.
Compared with the prior art, the application has the beneficial effects that:
(1) The water-flooding relative permeability experimental device is added on the traditional gas-flooding relative permeability experimental device, and the easy switching between two groups of experiments is realized only by two six-way valves. The operation is simple, the controllability is strong, the cost is low, and the measurement is accurate.
(2) And a water flooding experiment is carried out by using a large-size full-diameter rock core, so that the saturated gas in the rock core is high, and the measurement is convenient.
(3) And the experiment metering system adopts different metering modes for the gas-driven water and water-driven gas experiments. In the gas-driven water experiment, as the water quantity is less and the gas quantity is more, the mixed fluid at the outlet end of the core holder firstly measures water through a drying bottle, and the dried gas is measured through a gas measuring device. In the water flooding experiment, as the air quantity is less and the water quantity is more, the mixed fluid at the outlet end of the core holder firstly measures the air through a glass tube with scales, and meanwhile, the water quantity is measured through an electronic balance.
(4) It is proposed that the residual gas saturation of the water flooding experiment can be effectively changed by changing the number of injection capillary Ca. In stark contrast to conventional gas reservoirs or reservoir injection production. Increasing the number of injected capillary Ca, the relative permeability curve of water and gas shifts leftwards, and the shorter the anhydrous gas production period is, the less favorable the natural gas production is. For a water flooding gas reservoir, the process is equivalent to the fact that the higher the invasion speed of side water is, the shorter the anhydrous gas production period is, the gas well can quickly see water and is unfavorable for the exploitation of natural gas, and the saturation of residual gas is high. The reverse is true when the number of injection capillaries Ca is reduced. The slower the side water invasion speed is, the longer the anhydrous gas production period is, and the later the water breakthrough time of the gas well is, the higher the gas production amount is.
(5) The application has corresponding monitoring and verification methods in each experimental link, and in the gas flooding experiment process, nuclear magnetic resonance is adopted to obtain a gas-water distribution rule of the bound water state and the change of residual gas along with water injection time in the water flooding experiment process. After the water flooding experiment is finished, nuclear magnetic resonance T is utilized 2 Spectral correction and monitoring of the water-flooding experimental gas-water distribution law.
(6) In the experimental process, the application eliminates the influence of dead pore volume and reduces the experimental error.
(7) In the experimental process, the characteristic that the gas volume changes along with the pressure change is considered, the gas volume increment delta G' under the average pressure is used for participating in calculation, and the error of the gas phase relative permeability caused by the experimental condition change is reduced.
(8) The experimental method is simple, can simultaneously realize experimental study of the water-flooding gas reservoir formation process and the development process, simultaneously utilizes nuclear magnetic resonance T2 spectrum real-time monitoring, has high experimental precision and is little influenced by human errors.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present application, the following detailed description of the embodiments of the present application will be given with reference to the accompanying drawings, which are to be understood as merely some embodiments of the present application, and from which other drawings can be obtained by those skilled in the art without inventive faculty. Wherein:
FIG. 1 is a diagram of a gas-driven water and water-driven gas experiment device;
FIG. 2 is a graph showing the relative permeability of water-flooding gas at injection flow rates corresponding to different capillary numbers Ca (K: in the figure) rg (0.5 ml/min) gas phase relative permeability curve, K, for injection flow rate corresponding to low Ca rw (0.5 ml/min) is the relative permeability curve of the water phase with the injection flow rate corresponding to low Ca; k (K) rg (1.5 ml/min) is the gas phase relative permeability curve, K, of the injection flow corresponding to medium Ca rw (1.5 ml/min) is the relative permeability curve of the water phase corresponding to the injection flow rate of the medium Ca; k (K) rg (2.5 ml/min) gas phase relative permeability curve, K, for injection flow rate corresponding to high Ca rw (2.5 ml/min) is a relative permeability curve of the aqueous phase for injection flow rate corresponding to high Ca);
FIG. 3 is a nuclear magnetic resonance T2 spectrum of the water flooding experiment.
In the figure; 1. a nitrogen cylinder; 2. ISCO fluid injection pump; 3. an intermediate container; 4. a pressure sensor; 5. a pressure reducing valve; 6. a large-scale full-diameter core holder; 7, a high-precision confining pressure pump; 8. a pressure gauge; 9. an electronic balance; 10. drying the bottle; 11. glass tube with graduation; 12. a beaker; 13. a gas flow metering device.
Detailed Description
In order that the above objects, features and advantages of the application will be readily understood, a more particular description of the application will be rendered by reference to the appended drawings.
In the following description, numerous specific details are set forth in order to provide a thorough understanding of the present application, but the present application may be practiced in other ways other than those described herein, and persons skilled in the art will readily appreciate that the present application is not limited to the specific embodiments disclosed below.
Next, the present application will be described in detail with reference to the drawings, wherein the sectional view of the device structure is not partially enlarged to general scale for the convenience of description, and the drawings are only examples, which should not limit the scope of the present application. In addition, the three-dimensional dimensions of length, width and depth should be included in actual fabrication.
For the purpose of making the objects, technical solutions and advantages of the present application more apparent, embodiments of the present application will be described in further detail below with reference to the accompanying drawings.
Example 1
A water-flooding gas-relative permeability test method for a large-scale core with unsteady variable capillary number is characterized in that a water-flooding gas experimental device is additionally arranged on the basis of a traditional gas-flooding water experimental device and is used for completing the influence of water-flooding speed on natural gas recovery ratio and residual gas distribution rules in the water-flooding gas reservoir water-flooding process. The device (see figure 1) comprises an energy supply system, a nitrogen cylinder 1, an ISCO fluid injection pump 2, an intermediate container 3, a pressure sensor 4 and a pressure reducing valve 5, wherein stratum water is stored in the intermediate container 3; the experimental test system comprises a large-scale full-diameter core holder 6, a high-precision confining pressure pump 7 and a pressure gauge 8; the experimental test system comprises an electronic balance 9, a drying bottle 10, a graduated glass tube 11, a beaker 12 and a gas flow metering device 13; nuclear magnetic resonance T 2 A spectrum monitoring system 14. Loading the saturated water core into a large-scale full-diameter core holder 6, pressurizing the confining pressure to 15MPa by using a high-precision confining pressure pump 7, and closing the confining pressure pump to ensure that the pressure in the large-scale full-diameter confining pressure pump is kept unchanged at 15MPa in the experimental process. The left end of the large-scale full-diameter core holder 6 is connected with a six-way valve 14, one port of the six-way valve 14 is connected with a nitrogen cylinder 1 through a pressure reducing valve 5, the other port is connected with an ISCO fluid injection pump 2 through a pressure gauge 8 and an intermediate container 3, and simulated formation water in the intermediate container 3 is injected into the core holder in a constant flow or constant pressure mode through the ISCO fluid injection pump 2; the six-way valve is also provided with a pressure sensor 4 by which the pressure change of the injected gas or the injected liquid can be accurately monitored. The other end of the large-scale full-diameter core holder 6 is also connected with a six-way valve 14, one port of the six-way valve 14 firstly passes through a drying bottle (filled with anhydrous calcium chloride) 10, the drying bottle 10 is placed on an electronic balance 9, and the water quantity entering the drying bottle is metered through the electronic balance 9; the dried gas enters a gas flow metering device 13 for gas metering; the port is designed with less water due to more gas and less water in the air-driven water experiment process. When the gas-flooding experiment is carried out, the port is opened, and when the water-flooding experiment is carried out, the port is closed. The other port of the six-way valve 14 is connected to the graduated glass tube 11 through a pipeline, water is filled in the graduated glass tube 11, and the graduated glass tube 11 is inversely inserted into the beaker 12 for filling water and fixed; an electronic balance 9 is placed at the lower end of the beaker 12. When the water flooding experiment is carried out, the air quantity is small and the water quantity is large, and the trace air quantity can be accurately measured by adopting the method.
The method comprises the following specific steps:
s1, after coring from the study area, the porosity Φ=14.88% and the permeability k= 3.0622mD of the cored sample were measured, and X-diffraction was performed on the cored sample to obtain its mineral composition. An artificial large-scale full-diameter core with a corresponding porosity Φ=17.2% and permeability k= 3.0622mD was synthesized from the mineral composition of the cored sample. And (5) putting the artificial large-scale full-diameter core into an oven for drying for 48 hours, and then taking out. Its diameter d=7 cm, length l=10 cm, measured according to industry standards, and the cross-sectional area a=pi D calculated 2 /4＝38.465cm 2 Sample volume v=al= 384.650cm 3 Dry weight m1= 874.07g of the core sample is weighed under the condition of atmospheric pressure pa=0.1 MPa, and then the core sample after weighing the dry weight is placed into a vacuum pump to be vacuumized, pressurized and saturated to simulate stratum water KCL solution, and wet weight m2= 926.16g is weighed. Placing the core sample after the KCL solution is saturated into nuclear magnetic resonance T 2 In the monitoring system 14, T in the fully saturated state is scanned 2 A spectrogram.
S2, loading the core after the KCL solution is saturated into a large-scale full-diameter core holder 6, and connecting according to the connection mode shown in the figure 1. Firstly, performing an air flooding experiment to establish irreducible water saturation. The specific method comprises the following steps: the valve of the six-way valve at the left end of the core holder, which is connected with the nitrogen bottle 1, is opened, the valve of the ISCO fluid injection pump 2, which is connected with the dry bottle 10, is closed, and the valve of the glass tube with scales 11, which is connected with the right end of the six-way valve, is opened. In this case, the circuit shown in fig. 1 is an air-driven water experiment flow.
S3, establishing irreducible water saturation. The confining pressure is applied to the large-scale full-diameter core holder 6 by using the high-precision confining pressure pump 7 until the confining pressure reaches 15MPa, and then a valve of the confining pressure pump is closed, so that the core holder 6 is provided withThe confining pressure is always kept at 15 MPa. And opening the nitrogen bottle 1, and performing a gas flooding experiment according to the reference displacement pressure difference calculated by the formula 1 through a pressure reducing valve. The accumulated time is measured by a stopwatch during the experiment, the pressure sensor 4 measures the displacement pressure difference during the experiment, the electronic balance 9 measures the weight M3 of the absorption solution in the drying bottle 4, and the gas flow measuring device 13 measures the amount of the extracted gas. And stopping gas supply until the weight of the electronic balance 9 is not changed any more or the injected gas amount is more than 30 times of the pore volume of the core. The core weight M3 = 885.41g in the bound water state is weighed and the pore volume V in the bound water state is calculated Φ 。
Reference displacement differential pressure:
pore volume occupied by gas in bound water state: v (V) Φ ＝VΦ-(M3-M1)*μ w ＝45.91cm 3
S4, placing the core in the bound water state into nuclear magnetic resonance T 2 In the spectrum monitoring system 14, the distribution of bound water in the core is measured. And carrying out water flooding experiments under the action of different capillary numbers on the core in the bound water state. In the water flooding experiment, a valve connected with an ISCO fluid injection pump 2 is opened by a six-way valve at the left end of a large-scale full-diameter core holder 6, and a valve connected with a nitrogen bottle 1 is closed. And the right end of the large-scale full-diameter core holder 6 is closed to connect the valve of the drying bottle 10, and the valve of the glass tube 11 with scales is opened. The ISCO fluid injection pump 2 was adjusted so that the injection flow rates were respectively selected to be 0.5ml/min,1.5ml/min, and 2.5ml/min. By the capillary number calculation formula ca= (v μ) w )/σ gw And calculating the number of the injection capillary. The cumulative time Δt is recorded by a stopwatch, the cumulative gas production Δg increasing with time is measured by the change of the water level on the graduated glass tube 11, the displacement pressure difference Δp changing with time is read by the pressure sensor 4 connected to the left six-way valve 14, and the cumulative water production Δw increasing with time is read by the electronic balance 9 under the beaker 12. The following calculation formula of the relative permeability of the unsteady water-flooding gas along with the change of the capillary number is carried out:
according to the Darcy formula and the energy conservation law, the water saturation, the relative water phase permeability and the relative gas phase permeability in the water flooding process are deduced.
Water-flooding gas saturation:
water flooding gas water saturation S100-S
Relative permeability of aqueous phase:
gas phase relative permeability:
wherein:(As the gas has compressibility, the volume of the gas changes during the water flooding experiment, and ΔG' obtained here refers to the increment of the volume of the gas at the average pressure, which is a corrected value)
The application derives the water saturation S of the water flooding experiment o Relative permeability of aqueous phase K rw And gas phase relative permeability Kr g And (5) calculating a formula. And the change of the gas volume along with the pressure difference is considered in a gas phase relative permeability formula, and the cumulative gas yield under the average pressure of delta G' is solved.
S5, in the water flooding experiment process, selecting proper time for nuclear magnetic resonance T 2 Spectrum measurement to obtain a cluster of distribution rules of injected water in the core along with the increase of time according to nuclear magnetic resonance T 2 And (3) calculating the residual gas saturation by using the spectrogram, and comparing and correcting the residual gas saturation obtained by using the nuclear magnetic resonance T2 spectrum with a residual gas saturation value obtained by using a water flooding gas experiment to obtain an error range of the experiment.
Although the application has been described hereinabove with reference to embodiments, various modifications thereof may be made and equivalents may be substituted for elements thereof without departing from the scope of the application. In particular, the features of the disclosed embodiments may be combined with each other in any manner as long as there is no structural conflict, and the exhaustive description of these combinations is not given in this specification merely for the sake of omitting the descriptions and saving resources. Therefore, it is intended that the application not be limited to the particular embodiment disclosed, but that the application will include all embodiments falling within the scope of the appended claims.
Claims (2)
1. The method for testing the relative permeability of the unsteady variable-flow-rate large-scale rock core water flooding gas is characterized by comprising the following steps of:
step one: measuring the porosity phi and the permeability K of a core sample after coring from a research area, determining the range of the porosity phi and the permeability K by combining a logging curve of the research area, performing X-diffraction on the core sample to obtain mineral composition, synthesizing an artificial large-scale full-diameter core within the range of the corresponding porosity phi and the permeability K according to the mineral composition of the core sample, putting the artificial large-scale full-diameter core into a baking oven to be baked for 48 hours, taking out, measuring the diameter D, the length L, calculating the sectional area A, the porosity phi and the permeability K according to industry standards, weighing the dry weight M1 of the core sample under the atmospheric pressure Pa, putting the core sample after weighing the dry weight into a vacuum pump, vacuumizing and pressurizing to simulate stratum water KCL solution, weighing the wet weight M2, and putting the core sample after saturating the KCL solution into nuclear magnetic resonance T 2 In the monitoring system, T under the complete saturation state is scanned 2 A spectrogram;
step two: the core after saturated KCL solution is put into a large-scale full-diameter core holder, and an air-flooding water experiment is firstly carried out to establish the irreducible water saturation, and the specific method is as follows: the valve of the six-way valve at the left end of the core holder, which is connected with the nitrogen bottle (1), is opened, the valve of the ISCO fluid injection pump (2) is closed, the valve of the six-way valve at the right end of the core holder, which is connected with the drying bottle, is opened, the valve of the glass tube (11) with scales is closed, and the circuit is a gas-driven water experiment flow;
step three: establishing irreducible water saturation; large scale with high precision surrounding pressure pumpAfter confining pressure is added to 15MPa in the full-diameter core holder (6), closing a confining pressure pump valve, so that the confining pressure in the core holder is kept unchanged at 15MPa all the time; opening a nitrogen bottle (1), and performing a gas flooding experiment according to the reference displacement pressure difference calculated by the formula 1 through a pressure reducing valve; measuring the accumulated time by a stopwatch during the experiment, measuring the displacement pressure difference during the experiment by a pressure sensor (4), measuring the weight of the absorption solution in a drying bottle (10) by an electronic balance (9), and measuring the quantity of the extracted gas by a gas flow measuring device (13); stopping air supply until the weight of the electronic balance (9) is not changed any more or the injected gas amount is more than 30 times of the pore volume of the core; weigh the core weight M3 in the water-bound state and calculate the pore volume V occupied by the gas in the water-bound state Φ ；
V Φ ＝ALΦ-(M3-M1)*μ w
Wherein DeltaP 1 Is a reference displacement differential pressure;
step four: placing the core in the water-binding state into nuclear magnetic resonance T 2 In the spectrum monitoring system, measuring the distribution of the bound water in the rock core; carrying out water flooding experiments under the action of different capillary numbers on the core in the water-bound state; in the water flooding experiment, a six-way valve at the left end of a large-scale full-diameter core holder (6) is used for opening a valve connected with an ISCO fluid injection pump (2) and closing a valve connected with a nitrogen cylinder (1); the right six-way valve of the large-scale full-diameter core holder (6) closes a valve connected with the drying bottle (10), and opens a valve connected with the glass tube (11) with scales; the ISCO fluid injection pump (2) is regulated so that the injection flow rates are respectively 0.5ml/min,1.5ml/min and 2.5ml/min; by the capillary number calculation formula ca= (v μ) w )/σ gw Calculating the number of injection capillary tubes; recording the accumulated time delta t by a stopwatch, metering the accumulated gas yield delta G increased along with time by the change of the water level on a glass tube (11) with scales, reading the displacement pressure difference delta p along with time by a pressure sensor (4) connected with a left six-way valve (14), and reading the displacement pressure difference delta p along with time by an electronic balance (9) under a beaker (12)An increased cumulative water yield Δw;
the method comprises the steps of determining the water saturation, the relative water phase permeability and the relative gas phase permeability in the water flooding process according to a Darcy formula and an energy conservation law;
water-flooding gas saturation:
water flooding gas water saturation S w ＝100-S g ；
Relative permeability of aqueous phase:
gas phase relative permeability:
wherein:because the gas has compressibility, the gas volume can change in the water flooding experiment process, the delta G' obtained here refers to the increment of the gas volume under the average pressure, and the water saturation S of the water flooding experiment is deduced as a correction value w Relative permeability of aqueous phase K rw And relative permeability K of gas phase rg A calculation formula; the change of the gas volume along with displacement pressure difference is considered in a gas phase relative permeability formula, and the increment of the gas volume under the average pressure of delta G' is solved;
step five: in the water flooding experiment process, proper time is selected for nuclear magnetic resonance T 2 Spectrum measurement to obtain a cluster of distribution rules of injected water in the core along with the increase of time according to nuclear magnetic resonance T 2 And (3) calculating the residual gas saturation by using the spectrogram, and comparing and correcting the residual gas saturation obtained by using the nuclear magnetic resonance T2 spectrum with a residual gas saturation value obtained by using a water flooding gas experiment to obtain an error range of the experiment.
2. The method for testing the water-flooding gas relative permeability of the unsteady state variable flow rate large-scale rock core according to claim 1, wherein the method comprises the following steps of: adopts a water flooding experimental device and combines nuclear magnetic resonance T 2 The device is mainly completed by the following four systems including an energy supply system, an experimental test system, an experimental metering system and a nuclear magnetic resonance T 2 A spectrum monitoring system; the energy supply system comprises a nitrogen bottle (1), an ISCO fluid injection pump (2), an intermediate container (3), a pressure sensor (4) and a pressure reducing valve (5), wherein the intermediate container (3) stores stratum water; the experimental test system comprises a large-scale full-diameter core holder (6), a high-precision confining pressure pump (7) and a pressure gauge (8); the experiment metering system comprises an electronic balance (9), a drying bottle (10), a glass tube (11) with scales, a beaker (12) and a gas flow metering device (13); loading a core of saturated water into a large-scale full-diameter core holder (6), adding confining pressure to 15MPa by using a high-precision confining pressure pump (7), and closing the confining pressure pump to ensure that the pressure in the large-scale full-diameter confining pressure pump is kept unchanged at 15MPa in the experimental process; the left end of the large-scale full-diameter core holder (6) is connected with a six-way valve (14), one port of the six-way valve (14) is connected with a nitrogen cylinder (1) through a pressure reducing valve (5), the other port of the six-way valve is connected to an ISCO fluid injection pump (2) through a pressure gauge (8) and an intermediate container (3), and simulated formation water in the intermediate container (3) is injected into the core holder in a constant flow or constant pressure mode through the ISCO fluid injection pump (2); the six-way valve is also provided with a pressure sensor (4), and the pressure change of the injected gas or the injected liquid can be accurately monitored through the pressure sensor; the right end of the large-scale full-diameter core holder (6) is also connected with a six-way valve (14), one port of the six-way valve (14) is provided with a dry bottle (10) filled with anhydrous calcium chloride, the dry bottle is placed on an electronic balance (9), and the water quantity entering the dry bottle is measured through the electronic balance; the dried gas enters a gas flow metering device (13) for gas metering; the port is designed with less water because of more gas and less water in the air-driven water experiment process; when the gas-flooding experiment is carried out, the port is opened, and when the water-flooding experiment is carried out, the port is closed; another one of the six-way valve (14) at the right end of the core holderThe port is connected to the glass tube (11) with scales through a pipeline, water is filled in the glass tube (11) with scales, and the glass tube is inversely inserted into a beaker (12) filled with water and fixed; an electronic balance (9) is arranged at the lower end of the beaker (12); when the water flooding experiment is carried out, the air quantity is small and the water quantity is large, and the trace air quantity can be accurately measured by adopting the method.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110732812.5A CN113431537B (en) | 2021-06-30 | 2021-06-30 | Unsteady variable-flow-rate large-scale rock core water flooding gas relative permeability testing method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202110732812.5A CN113431537B (en) | 2021-06-30 | 2021-06-30 | Unsteady variable-flow-rate large-scale rock core water flooding gas relative permeability testing method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN113431537A CN113431537A (en) | 2021-09-24 |
| CN113431537B true CN113431537B (en) | 2023-12-12 |
Family
ID=77757945
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202110732812.5A Active CN113431537B (en) | 2021-06-30 | 2021-06-30 | Unsteady variable-flow-rate large-scale rock core water flooding gas relative permeability testing method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN113431537B (en) |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN114965216B (en) * | 2022-05-24 | 2023-04-07 | 重庆科技学院 | Rock multi-period cyclic load overburden pore volume experiment test system and test method |
| CN115234216B (en) * | 2022-05-25 | 2023-09-19 | 东营市永昇能源科技有限责任公司 | Method for establishing logging identification layout and application thereof |
| CN115788399B (en) * | 2022-11-07 | 2024-02-09 | 西南石油大学 | High-multiple water-drive rock core oil-water relative permeability curve measuring device and method |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20120330553A1 (en) * | 2011-06-27 | 2012-12-27 | Board Of Regents, The University Of Texas System | Method for generating a general enhanced oil recovery and waterflood forecasting model |
| CN104359819A (en) * | 2014-11-10 | 2015-02-18 | 中国石油天然气股份有限公司 | Device and method for determining gas-water relative permeability of low-infiltration dense rock core |
| US10167719B2 (en) * | 2013-09-03 | 2019-01-01 | Halliburton Energy Services, Inc. | Methods and systems for evaluation of rock permeability, porosity, and fluid composition |
| CN109916799A (en) * | 2019-03-22 | 2019-06-21 | 西南石油大学 | Measure the experimental method of the spontaneous Imbibition Relative Permeability of unconventional tight gas reservoir |
| CN110411905A (en) * | 2019-05-28 | 2019-11-05 | 西南石油大学 | A kind of high temperature and pressure shale unstable state air water mutually seeps test device and method |
| CN111878050A (en) * | 2020-08-25 | 2020-11-03 | 延安大学 | Method for improving recovery ratio through nuclear magnetism online compact oil-water flooding development |
| CN212748663U (en) * | 2020-08-11 | 2021-03-19 | 西南石油大学 | Unsteady gas-water phase seepage testing device |
-
2021
- 2021-06-30 CN CN202110732812.5A patent/CN113431537B/en active Active
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20120330553A1 (en) * | 2011-06-27 | 2012-12-27 | Board Of Regents, The University Of Texas System | Method for generating a general enhanced oil recovery and waterflood forecasting model |
| US10167719B2 (en) * | 2013-09-03 | 2019-01-01 | Halliburton Energy Services, Inc. | Methods and systems for evaluation of rock permeability, porosity, and fluid composition |
| CN104359819A (en) * | 2014-11-10 | 2015-02-18 | 中国石油天然气股份有限公司 | Device and method for determining gas-water relative permeability of low-infiltration dense rock core |
| CN109916799A (en) * | 2019-03-22 | 2019-06-21 | 西南石油大学 | Measure the experimental method of the spontaneous Imbibition Relative Permeability of unconventional tight gas reservoir |
| CN110411905A (en) * | 2019-05-28 | 2019-11-05 | 西南石油大学 | A kind of high temperature and pressure shale unstable state air water mutually seeps test device and method |
| CN212748663U (en) * | 2020-08-11 | 2021-03-19 | 西南石油大学 | Unsteady gas-water phase seepage testing device |
| CN111878050A (en) * | 2020-08-25 | 2020-11-03 | 延安大学 | Method for improving recovery ratio through nuclear magnetism online compact oil-water flooding development |
Also Published As
| Publication number | Publication date |
|---|---|
| CN113431537A (en) | 2021-09-24 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN113431537B (en) | Unsteady variable-flow-rate large-scale rock core water flooding gas relative permeability testing method | |
| CN109916799B (en) | Experimental method for measuring unconventional dense gas reservoir spontaneous imbibition relative permeability | |
| CN105910971B (en) | The simultaneous measuring method of rich organic matter compact rock core gas permeability and diffusion coefficient | |
| US7453266B2 (en) | Electronic humidity chamber for vapor desorption to determine high capillary pressures | |
| CN106814018A (en) | A kind of tight rock gas phase relative permeability measurement apparatus and method | |
| CN210264648U (en) | Multifunctional rock core displacement device | |
| CN113109546B (en) | Experimental device and method for predicting drying salt deposition range of reservoir of underground gas storage | |
| CN109138998A (en) | A kind of experimental test procedures of low permeability reservoir high temperature and pressure imbibition oil-recovering rate | |
| CN109883894A (en) | A kind of superhigh temperature super-pressure stable state air water mutually seeps test device and test method | |
| CN110672813A (en) | Shale gas content calculation method | |
| CN110161216A (en) | A kind of device and method measuring rock core irreducible water saturation | |
| CN109060639A (en) | A kind of measuring method of long cores permeability saturation curve | |
| CN113866069A (en) | Shale core permeability experiment device and method | |
| CN112964597A (en) | Multi-scale rock core adsorption-analysis-exploitation simulation experiment device and method | |
| CN114136861B (en) | Experimental system and evaluation method for drying salting-out effect of near-wellbore zone of gas storage | |
| CN115266800A (en) | Condensate oil saturation testing method based on two-dimensional nuclear magnetic resonance | |
| CN107727553B (en) | Device and method for measuring thick oil starting pressure gradient and seepage law | |
| CN207586089U (en) | A kind of viscous crude starting pressure gradient and percolation law measuring device | |
| CN107907464B (en) | Device and method for measuring performance of permeable stone cement slurry for fracturing | |
| CN108153944A (en) | A kind of stress sensitive reservoir water-producing gas well natural gas single well controlled reserves determine method | |
| CN111238988B (en) | Experimental device and method for measuring efficiency of supercritical carbon dioxide in dense oil core to replace crude oil | |
| CN111638158A (en) | Compact sandstone gas-water phase permeability testing device and method based on capacitance method | |
| CN105929135B (en) | A kind of method of testing of low permeability gas reservoir reserves exploitation degree | |
| CN115598040B (en) | Device and method for measuring two-way permeability coefficient of pore medium | |
| CN113670768B (en) | Method, device and system for determining sea phase shale in-situ gas volume recovery |
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 | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |