CN116448343A - Device and method for predicting underground hydrogen storage leakage pressure - Google Patents
Device and method for predicting underground hydrogen storage leakage pressure Download PDFInfo
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- 239000001257 hydrogen Substances 0.000 title claims abstract description 109
- 229910052739 hydrogen Inorganic materials 0.000 title claims abstract description 109
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 title claims abstract description 107
- 238000000034 method Methods 0.000 title claims abstract description 16
- 239000007789 gas Substances 0.000 claims abstract description 65
- 239000011435 rock Substances 0.000 claims abstract description 20
- 238000004364 calculation method Methods 0.000 claims abstract description 12
- 239000012266 salt solution Substances 0.000 claims abstract description 6
- 230000008859 change Effects 0.000 claims abstract description 5
- 238000009738 saturating Methods 0.000 claims abstract description 5
- 238000009792 diffusion process Methods 0.000 claims description 25
- 230000006835 compression Effects 0.000 claims description 14
- 238000007906 compression Methods 0.000 claims description 14
- 239000007788 liquid Substances 0.000 claims description 14
- 239000002699 waste material Substances 0.000 claims description 13
- 238000006073 displacement reaction Methods 0.000 claims description 12
- 230000015572 biosynthetic process Effects 0.000 claims description 9
- 238000012545 processing Methods 0.000 claims description 8
- 239000012530 fluid Substances 0.000 claims description 5
- 238000002347 injection Methods 0.000 claims description 5
- 239000007924 injection Substances 0.000 claims description 5
- 230000004913 activation Effects 0.000 claims description 4
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 4
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 3
- 238000001802 infusion Methods 0.000 claims description 3
- 230000006641 stabilisation Effects 0.000 claims description 3
- 238000011105 stabilization Methods 0.000 claims description 3
- 230000005540 biological transmission Effects 0.000 claims description 2
- 230000002265 prevention Effects 0.000 abstract 1
- 239000000126 substance Substances 0.000 description 4
- 238000011161 development Methods 0.000 description 3
- 150000002431 hydrogen Chemical class 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- 238000009795 derivation Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 238000004146 energy storage Methods 0.000 description 1
- 239000002803 fossil fuel Substances 0.000 description 1
- 239000005431 greenhouse gas Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000012502 risk assessment Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
- 238000010792 warming Methods 0.000 description 1
Classifications
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- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
- G06F17/10—Complex mathematical operations
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
- G01M3/00—Investigating fluid-tightness of structures
- G01M3/02—Investigating fluid-tightness of structures by using fluid or vacuum
- G01M3/26—Investigating fluid-tightness of structures by using fluid or vacuum by measuring rate of loss or gain of fluid, e.g. by pressure-responsive devices, by flow detectors
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume, or surface-area of porous materials
- G01N15/08—Investigating permeability, pore-volume, or surface area of porous materials
- G01N15/082—Investigating permeability by forcing a fluid through a sample
- G01N15/0826—Investigating permeability by forcing a fluid through a sample and measuring fluid flow rate, i.e. permeation rate or pressure change
-
- 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
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
- Y02E60/30—Hydrogen technology
- Y02E60/32—Hydrogen storage
Abstract
The invention discloses a device and a method for predicting underground hydrogen storage leakage pressure, wherein the method comprises the following steps: s1: acquiring a reservoir core and a overburden core, and respectively clamping the reservoir core and the overburden core in a first core holder and a second core holder; s2: vacuumizing the device; s3: simulating the temperature and pressure of the reservoir and the cap layer; s4: saturating the stratum salt solution of the reservoir and the overburden core; s5: injecting hydrogen into the first rock core holder, and observing the pressure change condition of the third pressure sensor; s6: when the indication of the pressure sensor III or the gas flowmeter II is larger than zero and the indication is stable, recording the indication of each pressure sensor and each gas flowmeter at the moment; s7: and (3) establishing a calculation model of the equivalent critical breakthrough pressure under the laboratory condition, and calculating the equivalent critical breakthrough pressure under the laboratory condition by combining the data obtained in the step (S6), wherein the breakthrough pressure is the underground hydrogen storage leakage pressure. The invention can accurately predict the leakage pressure of underground hydrogen storage and provide technical support for the leakage prevention of the hydrogen storage.
Description
Technical Field
The invention relates to the technical field of hydrogen storage and energy storage, in particular to a device and a method for predicting underground hydrogen storage leakage pressure.
Background
As fossil fuels are used and exhausted excessively, excessive emission of greenhouse gases causes global warming. Hydrogen is regarded as the clean energy with the most development potential in the 21 st century, plays an important supporting role for green transformation development of energy, and is a key development direction of strategic emerging industry and future industry.
At present, the hydrogen storage modes comprise physical adsorption hydrogen storage, ground container hydrogen storage, porous medium hydrogen storage and the like, and the hydrogen storage warehouse stores hydrogen through the porous medium by utilizing rocks, so that the hydrogen storage warehouse has the characteristics of high safety, low economic cost, small occupied ground space and the like, and the hydrogen can be stored underground for a long time. However, for higher cap permeability, viscous fingering occurs, increasing the potential loss of hydrogen. Once the hydrogen leakage occurs, the hydrogen storage amount is severely reduced, so that the loss is caused economically, and even chemical reactions and the like are caused, and the safety problems of a shaft, a stratum and the like are affected.
Therefore, in order to ensure that the hydrogen storage tank can operate efficiently and safely for a long period of time, it is necessary to prevent the problem that hydrogen is affected by pressure as much as possible so as to reduce the risk of leakage of the hydrogen storage tank. And the leakage risk assessment and countermeasure research of the hydrogen storage are carried out, and the critical breakthrough pressure research of the leakage of the hydrogen breakthrough cover layer of the hydrogen storage is carried out, so that the method has urgent practical significance for ensuring the long-acting safe operation of the hydrogen storage and the safe supply of regional energy sources.
Disclosure of Invention
In view of the foregoing, the present invention is directed to an apparatus and method for predicting the leakage pressure of hydrogen stored underground.
The technical scheme of the invention is as follows:
on one hand, a device for predicting the leakage pressure of underground hydrogen storage is provided, which comprises an input system, a first core holder, a second core holder, a waste liquid collecting tank, a first confining pressure pump, a second confining pressure pump, a first incubator and a second incubator;
the first constant temperature box is used for simulating the temperature of a reservoir, the first core holder is used for clamping the core of the reservoir and is arranged in the first constant temperature box, the first confining pressure pump is connected with the first core holder, and a valve I is arranged on a connected pipeline;
the second incubator is used for simulating the temperature of the overburden, the second core holder is used for holding the overburden core and is arranged in the second incubator, the confining pressure pump II is connected with the second core holder, and a valve II is arranged on a connected pipeline;
the input system, the first core holder, the second core holder and the waste liquid collecting tank are sequentially connected, a first pressure sensor and a first gas flowmeter are sequentially arranged on a pipeline between the input system and the first core holder, a second pressure sensor is arranged on a pipeline between the first core holder and the second core holder, a third pressure sensor, a second gas flowmeter and a third valve are sequentially arranged on a pipeline between the second core holder and the waste liquid collecting tank, and the third valve can ensure that fluid can only flow from the core holder to the waste liquid collecting tank;
the input system comprises a gas pipeline and a transfusion pipeline which are arranged in parallel, and the output end of the gas pipeline and the output end of the transfusion pipeline are connected with the input end of the first rock core holder through a three-way valve;
the gas transmission pipeline comprises a high-pressure gas storage tank and a gas humidifying device which are connected, and a pressure reducing valve is arranged on the connected pipeline; the output end of the gas humidifying device is connected with one of the input ends of the three-way valve, and a valve IV is arranged on the connected pipeline;
the infusion pipeline comprises a displacement pump and an intermediate container which are connected, and a valve V is arranged on the connected pipeline; stratum salt solution is arranged in the intermediate container, the output end of the intermediate container is connected with the other input end of the three-way valve, and a valve six is arranged on a connected pipeline.
Preferably, the first pressure sensor and the first gas flow meter are arranged in the first incubator, and the third pressure sensor and the second gas flow meter are arranged in the second incubator.
Preferably, the second pressure sensor is disposed in the first incubator, in the second incubator, or between the first incubator and the second incubator.
Preferably, the third valve adopts a check valve.
Preferably, the system further comprises a data processing system, wherein the first pressure sensor, the second pressure sensor, the third pressure sensor, the first gas flowmeter and the second gas flowmeter are connected with the data processing system.
In another aspect, there is also provided a method for predicting an underground hydrogen storage leak pressure, the apparatus for predicting an underground hydrogen storage leak pressure according to any one of the above, comprising the steps of:
s1: acquiring a reservoir core and a overburden core, and clamping the reservoir core and the overburden core in the first core holder and the second core holder respectively;
s2: vacuumizing the device for predicting the leakage pressure of the underground hydrogen storage;
s3: opening the confining pressure pump I, the valve I and the constant temperature box I, and simulating the reservoir temperature and the reservoir pressure; starting the confining pressure pump II, the valve II and the constant temperature box II, and simulating the temperature and the pressure of the cover layer;
s4: starting the displacement pump, the valve five, the valve six and the valve three, saturating stratum saline solution on the reservoir core and the overburden core, and closing the displacement pump, the valve five, the valve six and the valve three after saturation;
s5: opening the pressure reducing valve, the valve IV and the valve III, injecting hydrogen into the core holder I, and observing the pressure change condition of the pressure sensor III;
s6: when the indication of the pressure sensor III or the gas flowmeter II is larger than zero and the indication is stable, recording the indication of each pressure sensor and each gas flowmeter at the moment;
s7: and (3) establishing a calculation model of the equivalent critical breakthrough pressure under the laboratory condition, and calculating the equivalent critical breakthrough pressure under the laboratory condition by combining the data obtained in the step (S6), wherein the breakthrough pressure is the underground hydrogen storage leakage pressure.
Preferably, in step S6, the calculation model is:
wherein: p (P) l The equivalent critical breakthrough pressure of hydrogen under laboratory conditions, pa; p (P) 2 Indicating the pressure Pa of a second pressure sensor; s is S H For solubility of hydrogen in the reservoir, nm 3 /m 3 ；Z f Is a compression factor under stratum conditions, and is dimensionless; p (P) o Is the pressure under standard conditions, pa; d (D) lc For the diffusion coefficient of hydrogen in the cap layer under laboratory conditions, m 2 /s；H lc Length of the overburden core, m, under laboratory conditions; d (D) lr For the diffusion coefficient of hydrogen in the reservoir under laboratory conditions, m 2 /s；H lr The length, m, of the reservoir core under laboratory conditions; phi (phi) d Is interface porosity, dimensionless; t is the time from the beginning of hydrogen injection to the stabilization of three readings of the pressure sensor, and s; t (T) lc The temperature K of the overburden core under laboratory conditions; t (T) lr The temperature, K, of the reservoir core under laboratory conditions; d, d lr The diameter, m, of the reservoir core under laboratory conditions; z is Z lc The compression factor of the overburden core under laboratory conditions is dimensionless; y is Y H Is the volume fraction of hydrogen in the gas, and is dimensionless; phi is the porosity of the reservoir rock and is dimensionless; s is S wi To irreducible water saturation, dimensionless; t (T) o Is the temperature under standard conditions, K; h fr The thickness of the reservoir layer under stratum conditions, m; d, d lc The diameter, m, of a reservoir core under formation conditions; z is Z lr Is the compression factor of the reservoir rock core under laboratory conditions, and has no dimension.
Preferably, the diffusion coefficient of hydrogen in the reservoir under laboratory conditions and the diffusion coefficient of hydrogen in the cap layer under laboratory conditions are calculated by the following formula:
wherein: d (D) fr And D fc Diffusion coefficient of hydrogen in reservoir and cap layer under formation conditions, m 2 S; q is diffusion activation energy, J/mol; r is the gas constant, J/(mol.K).
The beneficial effects of the invention are as follows:
the invention can simulate real stratum conditions; by arranging two core holders in series to respectively hold the reservoir core and the overburden core and arranging a pressure sensor between the two core holders, the amount of substances can be more accurately determined, so that a more accurate calculation model is built, and the equivalent critical breakthrough pressure of hydrogen under more accurate laboratory conditions is calculated and obtained.
Drawings
In order to more clearly illustrate the embodiments of the invention or the technical solutions of the prior art, the drawings which are used in the description of the embodiments or the prior art will be briefly described, it being obvious that the drawings in the description below are only some embodiments of the invention, and that other drawings can be obtained according to these drawings without inventive faculty for a person skilled in the art.
FIG. 1 is a schematic diagram of an apparatus for predicting the leakage pressure of hydrogen stored underground according to the present invention.
Reference numerals in the drawings: the device comprises a 1-high-pressure air storage tank, a 2-pressure reducing valve, a 3-gas humidifying device, a 4-valve five, a 5-valve one, a 6-valve two, a 7-displacement pump, an 8-surrounding pressure pump one, a 9-surrounding pressure pump two, a 10-valve four, a 11-valve six, a 12-pressure sensor one, a 13-pressure sensor two, a 14-pressure sensor three, a 15-core holder one, a 16-core holder two, a 17-gas flowmeter one, a 18-gas flowmeter two, a 19-valve three, a 20-waste liquid collecting tank, a 21-intermediate container, a 22-incubator one and a 23-incubator two.
Detailed Description
The invention will be further described with reference to the drawings and examples. It should be noted that, without conflict, the embodiments and technical features of the embodiments in the present application may be combined with each other. It is noted that all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs unless otherwise indicated. The use of the terms "comprising" or "includes" and the like in this disclosure is intended to cover a member or article listed after that term and equivalents thereof without precluding other members or articles.
In one aspect, as shown in fig. 1, the invention provides a device for predicting underground hydrogen storage leakage pressure, which comprises an input system, a first core holder 15, a second core holder 16, a waste liquid collecting tank 20, a first confining pressure pump 8, a second confining pressure pump 9, a first constant temperature box 22 and a second constant temperature box 23;
the first incubator 22 is used for simulating the temperature of a reservoir, the first core holder 15 is used for clamping the core of the reservoir and is arranged in the first incubator 22, the first confining pressure pump 8 is connected with the first core holder 15, and a valve I5 is arranged on a connected pipeline;
the second incubator 23 is used for simulating the temperature of the overburden, the second core holder 16 is used for holding the overburden core and is arranged in the second incubator 23, the second confining pressure pump 9 is connected with the second core holder 16, and a second valve 6 is arranged on a connected pipeline;
the input system, the first core holder 15, the second core holder 16 and the waste liquid collection tank 20 are sequentially connected, a first pressure sensor 12 and a first gas flowmeter 17 are sequentially arranged on a pipeline between the input system and the first core holder 15, a second pressure sensor 13 is arranged on a pipeline between the first core holder 15 and the second core holder 16, a third pressure sensor 14, a second gas flowmeter 18 and a third valve 19 are sequentially arranged on a pipeline between the second core holder 16 and the waste liquid collection tank 20, and the third valve 19 can ensure that fluid can only flow from the second core holder 16 to the waste liquid collection tank 20;
the input system comprises a gas pipeline and a transfusion pipeline which are arranged in parallel, and the output end of the gas pipeline and the output end of the transfusion pipeline are connected with the input end of the first core holder 15 through a three-way valve;
the gas pipeline comprises a high-pressure gas storage tank 1 and a gas humidifying device 3 which are connected, and a pressure reducing valve 2 is arranged on the connected pipeline; the output end of the gas humidifying device 3 is connected with one of the input ends of the three-way valve, and a valve IV 10 is arranged on the connected pipeline;
the infusion pipeline comprises a displacement pump 7 and an intermediate container 21 which are connected, and a valve five 4 is arranged on the connected pipeline; stratum salt solution is arranged in the intermediate container 21, the output end of the intermediate container 21 is connected with the other input end of the three-way valve, and a valve six 11 is arranged on the connected pipeline.
In a specific embodiment, the first pressure sensor and the first gas flow meter are disposed in the first incubator, the third pressure sensor and the second gas flow meter are disposed in the second incubator, and the second pressure sensor is disposed in the first incubator, the second incubator, or between the first incubator and the second incubator.
In a specific embodiment, the valve III employs a check valve. It should be noted that, besides the check valve, the present invention may also use other valves to realize the function of unidirectional fluid flow, for example, the third valve adopts two valves, one of which is a unidirectional valve, and the unidirectional valve is disposed between the other valve and the second core holder, so as to realize the function required by the present invention.
In a specific embodiment, the device of the present invention further comprises a data processing system (not shown in the figure), and the first pressure sensor, the second pressure sensor, the third pressure sensor, the first gas flow meter and the second gas flow meter are all connected to the data processing system. In this embodiment, the data processing system may be a computer, or the data processing system may be a computer, so that the readings of each pressure sensor and each gas flowmeter may be acquired more conveniently and intelligently.
It should be noted that, the sub-components such as the gas humidifying device, the intermediate container, the core holder and the like adopted in the invention are all in the prior art, and specific structures are not described herein.
In another aspect, the present invention also provides a method for predicting an underground hydrogen storage leakage pressure, where the predicting device for predicting an underground hydrogen storage leakage pressure according to any one of the above-mentioned embodiments is used for predicting, and the method includes the following steps:
s1: and acquiring a reservoir core and a overburden core, and clamping the reservoir core and the overburden core in the first core holder and the second core holder respectively.
S2: and vacuumizing the device for predicting the leakage pressure of the underground hydrogen storage.
S3: opening the confining pressure pump I, the valve I and the constant temperature box I, and simulating the reservoir temperature and the reservoir pressure; and opening the confining pressure pump II, the valve II and the constant temperature box II to simulate the temperature and the pressure of the cover layer.
S4: and (3) starting the displacement pump, the valve five, the valve six and the valve three, saturating stratum saline solution on the reservoir core and the overburden core, and closing the displacement pump, the valve five, the valve six and the valve three after saturation.
S5: and opening the pressure reducing valve, the valve IV and the valve III, injecting hydrogen into the core holder I, and observing the pressure change condition of the pressure sensor III.
S6: and when the readings of the pressure sensor III or the gas flowmeter II are larger than zero and the readings are stable, recording the readings of each pressure sensor and each gas flowmeter at the moment.
S7: and (3) establishing a calculation model of the equivalent critical breakthrough pressure under the laboratory condition, and calculating the equivalent critical breakthrough pressure under the laboratory condition by combining the data obtained in the step (S6), wherein the breakthrough pressure is the underground hydrogen storage leakage pressure.
In a specific embodiment, in step S6, the calculation model is:
wherein: p (P) l The equivalent critical breakthrough pressure of hydrogen under laboratory conditions, pa; p (P) 2 Indicating the pressure Pa of a second pressure sensor; s is S H For solubility of hydrogen in the reservoir, nm 3 /m 3 ；Z f Is a compression factor under stratum conditions, and is dimensionless; p (P) o Is the pressure under standard conditions, pa; d (D) lc For the diffusion coefficient of hydrogen in the cap layer under laboratory conditions, m 2 /s；H lc Length of the overburden core, m, under laboratory conditions; d (D) lr For the diffusion coefficient of hydrogen in the reservoir under laboratory conditions, m 2 /s；H lr The length, m, of the reservoir core under laboratory conditions; phi (phi) d Is interface porosity, dimensionless; t is the time from the beginning of hydrogen injection to the stabilization of three readings of the pressure sensor, and s; t (T) lc The temperature K of the overburden core under laboratory conditions; t (T) lr The temperature, K, of the reservoir core under laboratory conditions; d, d lr The diameter, m, of the reservoir core under laboratory conditions; z is Z lc The compression factor of the overburden core under laboratory conditions is dimensionless; y is Y H Is the volume fraction of hydrogen in the gas, and is dimensionless; phi is the porosity of the reservoir rock and is dimensionless; s is S wi To irreducible water saturation, dimensionless; t (T) o Is the temperature under standard conditions, K; h fr The thickness of the reservoir layer under stratum conditions, m; d, d lc The diameter, m, of a reservoir core under formation conditions; z is Z lr Is the compression factor of the reservoir rock core under laboratory conditions, and has no dimension.
The above-mentioned calculation model is obtained by deriving the following steps:
equivalent pressure under laboratory conditions was calculated:
wherein: n is the amount of hydrogen species, mol; v (V) l Is the volume of hydrogen under laboratory conditions, m 3 ；P l The pressure of hydrogen under laboratory conditions, pa; r is a gas constant, J/(mol.K); t (T) l Is the temperature of hydrogen under laboratory conditions, K; t (T) f K is the temperature of formation hydrogen; p (P) f Is the pressure of the formation hydrogen, pa.
At the same time, in the formation:
V h ＝V r φ(S g -S gi ) (6)
wherein: v (V) h For the hydrogen capacity in the rock, m 3 ；V r M is the total volume of the rock 3 ；S g The volume fraction of hydrogen in the reservoir is dimensionless; s is S gi There is no dimension to the volume fraction that actually remains in the reservoir when all the gas is produced to the minimum allowed flow pressure.
The equivalent pressure is therefore:
wherein: a is the ratio of the amount of hydrogen species entering the cap layer to the amount of hydrogen species in the reservoir, dimensionless;
and is also provided with
Wherein: v (V) lr Is the volume of hydrogen in the reservoir core under laboratory conditions, m 3 ；Z lr Is a laboratory conditionThe compression factor of the core of the lower reservoir is dimensionless; n is n 1 The amount, mol, of material of the reservoir core under laboratory conditions; p (P) 3 Indicating the pressure Pa of the third pressure sensor; v (V) lc The volume of hydrogen in the cap layer core, m, under laboratory conditions 3 ；Z lc The compression factor of the overburden core under laboratory conditions is dimensionless; n is n 2 Is the amount, mol, of material of the overburden core under laboratory conditions.
Thus, the calculation model represented by the formula (1) of the present invention can be obtained by derivation.
Because the pressure gradient changes when hydrogen is injected to perform gas drive, the pressure when the pressure gradient enters the core of the cap layer correspondingly changes, and thus the quantity of substances can be influenced, if only one core holder is arranged, the core which comprises both the reservoir layer and the cap layer is arranged in the core holder, the quantity of the substances cannot be accurately obtained, and thus, a more accurate pressure prediction result for breaking through the cap layer cannot be obtained.
The device for predicting the underground hydrogen storage leakage pressure is provided with two core holders which are connected in series and are respectively used for holding a reservoir core and a overburden core, and a pressure sensor is arranged between the two core holders, so that the quantity of substances can be more accurately determined, and the equivalent pressure of a breakthrough overburden can be more accurately predicted by the calculation model.
In addition, when the calculation model of the invention calculates equivalent pressure, the adopted diffusion coefficient is not the diffusion coefficient of the stratum directly adopted, but the diffusion coefficient is equally equivalent, so that the obtained result is more accurate.
Alternatively, the diffusion coefficient of hydrogen in the reservoir under laboratory conditions and the diffusion coefficient of hydrogen in the cap layer under laboratory conditions are calculated by the following equations, respectively:
wherein: d (D) fr And D fc Diffusion coefficient of hydrogen in reservoir and cap layer under formation conditions, m 2 S; q is diffusion activation energy, J/mol.
In a specific embodiment, taking a certain target area as an example, the method for predicting the underground hydrogen storage leakage pressure is used for predicting the underground hydrogen storage leakage pressure. The geological survey and the core test show that the height of the cover layer and the reservoir layer of the target area are respectively 30m and 170m, and the diffusion coefficient of the cover layer and the reservoir layer under the stratum condition is respectively 1.2 x 10 -9 m 2 S and 2.3 x 10 -8 m 2 Per s, a gas constant of 8.314J/(mol.K), a diffusion activation energy of 19297.06J/mol, a solubility of hydrogen in the reservoir of 2.1Nm 3 /m 3 The compression factor of reservoir rock under stratum condition is 1.1, the interfacial porosity is 0.01, the rock porosity is 0.121, the irreducible water saturation is 0.2, the volume fraction of hydrogen in gas is 90%, the compression factor of reservoir rock under laboratory condition is 0.94, the compression factor of reservoir rock is 1.01, the length of reservoir rock under laboratory condition is 6cm, the length of overburden rock is 2cm, the diameter of reservoir rock is 3.16cm, and the length of overburden rock is 3.04 cm. The method specifically comprises the following steps:
(1) Preparing a reservoir core and a overburden core, cleaning and drying the reservoir core and the overburden core, and measuring the length and the diameter of the reservoir core and the overburden core;
(2) Preparing a fluid, storing a hydrogen sample of an actual gas reservoir in the high-pressure gas storage tank, storing liquid in the actual gas reservoir in a gas humidifying device, and storing stratum salt solution in an intermediate container;
(3) The connection relation of the device for predicting the leakage pressure of the underground hydrogen storage according to the invention connects the sub-components and checks the air tightness of the device;
(4) Vacuumizing the device;
(5) Starting the confining pressure pump I8, the valve I5 and the constant temperature box I22, and simulating reservoir temperature and reservoir pressure; starting the confining pressure pump II 9, the valve II 6 and the constant temperature box II 23, and simulating the temperature and the pressure of the cover layer; in this embodiment, the simulated reservoir temperature is 283K and the simulated cap temperature is 288K;
(6) Starting the displacement pump 7, the valve five 4, the valve six 11 and the valve three 19, saturating stratum salt solution on the reservoir core and the overburden core, and closing the displacement pump 7, the valve five 4, the valve six 11 and the valve three 19 after saturation;
(7) Opening the pressure reducing valve 2, the valve IV 10 and the valve III 19, injecting hydrogen into the first core holder 15, and observing the pressure change condition of the pressure sensor III 14;
(8) When the readings of the pressure sensor III 14 or the gas flowmeter II 18 are larger than zero and the readings are stable, the readings of each pressure sensor and each gas flowmeter at the moment are recorded, the readings of the pressure sensor II 13 at the moment are 8000Pa, the readings of the pressure sensor III 14 are 3000Pa, and the time from the beginning of hydrogen injection to the moment is 10 days;
(9) Calculating the equivalent diffusion coefficient according to the formula (2) and the formula (3), and obtaining the diffusion coefficient of the hydrogen in the cover layer under the laboratory condition of 4.376×10 -6 m 2 Hydrogen diffusion coefficient in reservoir at laboratory conditions of 7.274 x 10 -5 m 2 /s；
(10) And calculating the equivalent critical breakthrough pressure under the laboratory condition according to the formula (1), and obtaining the equivalent critical breakthrough pressure under the laboratory condition as 16538.48Pa.
In this embodiment, when the hydrogen injection pressure exceeds 16538.48Pa, the hydrogen breaks through the cap layer, resulting in safety and economic risks such as leakage.
In summary, the method and the device can more accurately predict the underground hydrogen storage leakage pressure. Compared with the prior art, the invention has obvious progress.
The present invention is not limited to the above-mentioned embodiments, but is intended to be limited to the following embodiments, and any modifications, equivalents and modifications can be made to the above-mentioned embodiments without departing from the scope of the invention.
Claims (8)
1. The device for predicting the leakage pressure of the underground hydrogen storage is characterized by comprising an input system, a first core holder, a second core holder, a waste liquid collecting tank, a first confining pressure pump, a second confining pressure pump, a first constant temperature box and a second constant temperature box;
the first constant temperature box is used for simulating the temperature of a reservoir, the first core holder is used for clamping the core of the reservoir and is arranged in the first constant temperature box, the first confining pressure pump is connected with the first core holder, and a valve I is arranged on a connected pipeline;
the second incubator is used for simulating the temperature of the overburden, the second core holder is used for holding the overburden core and is arranged in the second incubator, the confining pressure pump II is connected with the second core holder, and a valve II is arranged on a connected pipeline;
the input system, the first core holder, the second core holder and the waste liquid collecting tank are sequentially connected, a first pressure sensor and a first gas flowmeter are sequentially arranged on a pipeline between the input system and the first core holder, a second pressure sensor is arranged on a pipeline between the first core holder and the second core holder, a third pressure sensor, a second gas flowmeter and a third valve are sequentially arranged on a pipeline between the second core holder and the waste liquid collecting tank, and the third valve can ensure that fluid can only flow from the core holder to the waste liquid collecting tank;
the input system comprises a gas pipeline and a transfusion pipeline which are arranged in parallel, and the output end of the gas pipeline and the output end of the transfusion pipeline are connected with the input end of the first rock core holder through a three-way valve;
the gas transmission pipeline comprises a high-pressure gas storage tank and a gas humidifying device which are connected, and a pressure reducing valve is arranged on the connected pipeline; the output end of the gas humidifying device is connected with one of the input ends of the three-way valve, and a valve IV is arranged on the connected pipeline;
the infusion pipeline comprises a displacement pump and an intermediate container which are connected, and a valve V is arranged on the connected pipeline; stratum salt solution is arranged in the intermediate container, the output end of the intermediate container is connected with the other input end of the three-way valve, and a valve six is arranged on a connected pipeline.
2. The apparatus for predicting an underground hydrogen storage leak pressure of claim 1, wherein the first pressure sensor and the first gas flow meter are disposed in the first incubator, and the third pressure sensor and the second gas flow meter are disposed in the second incubator.
3. The apparatus for predicting an underground hydrogen storage leak pressure as recited in claim 1 or 2, wherein the second pressure sensor is provided in the first incubator, in the second incubator, or between the first incubator and the second incubator.
4. The apparatus for predicting the leakage pressure of hydrogen storage in the ground as set forth in claim 1, wherein said valve three employs a check valve.
5. The apparatus for predicting the leak pressure of an underground hydrogen storage of claim 1, further comprising a data processing system, wherein the first pressure sensor, the second pressure sensor, the third pressure sensor, the first gas flow meter, and the second gas flow meter are coupled to the data processing system.
6. A method of predicting an underground hydrogen storage leak pressure, characterized by using the apparatus for predicting an underground hydrogen storage leak pressure according to any one of claims 1 to 5, comprising the steps of:
s1: acquiring a reservoir core and a overburden core, and clamping the reservoir core and the overburden core in the first core holder and the second core holder respectively;
s2: vacuumizing the device for predicting the leakage pressure of the underground hydrogen storage;
s3: opening the confining pressure pump I, the valve I and the constant temperature box I, and simulating the reservoir temperature and the reservoir pressure; starting the confining pressure pump II, the valve II and the constant temperature box II, and simulating the temperature and the pressure of the cover layer;
s4: starting the displacement pump, the valve five, the valve six and the valve three, saturating stratum saline solution on the reservoir core and the overburden core, and closing the displacement pump, the valve five, the valve six and the valve three after saturation;
s5: opening the pressure reducing valve, the valve IV and the valve III, injecting hydrogen into the core holder I, and observing the pressure change condition of the pressure sensor III;
s6: when the indication of the pressure sensor III or the gas flowmeter II is larger than zero and the indication is stable, recording the indication of each pressure sensor and each gas flowmeter at the moment;
s7: and (3) establishing a calculation model of the equivalent critical breakthrough pressure under the laboratory condition, and calculating the equivalent critical breakthrough pressure under the laboratory condition by combining the data obtained in the step (S6), wherein the breakthrough pressure is the underground hydrogen storage leakage pressure.
7. The method of predicting hydrogen storage leak pressure in the subsurface of claim 6, wherein in step S6, the calculation model is:
wherein: p (P) l The equivalent critical breakthrough pressure of hydrogen under laboratory conditions, pa; p (P) 2 Indicating the pressure Pa of a second pressure sensor; s is S H For solubility of hydrogen in the reservoir, nm 3 /m 3 ；Z f Is a compression factor under stratum conditions, and is dimensionless; p (P) o Is the pressure under standard conditions, pa; d (D) lc For hydrogen in the cover layer under laboratory conditionsDiffusion coefficient m of 2 /s；H lc Length of the overburden core, m, under laboratory conditions; d (D) lr For the diffusion coefficient of hydrogen in the reservoir under laboratory conditions, m 2 /s；H lr The length, m, of the reservoir core under laboratory conditions; phi (phi) d Is interface porosity, dimensionless; t is the time from the beginning of hydrogen injection to the stabilization of three readings of the pressure sensor, and s; t (T) lc The temperature K of the overburden core under laboratory conditions; t (T) lr The temperature, K, of the reservoir core under laboratory conditions; d, d lr The diameter, m, of the reservoir core under laboratory conditions; z is Z lc The compression factor of the overburden core under laboratory conditions is dimensionless; y is Y H Is the volume fraction of hydrogen in the gas, and is dimensionless; phi is the porosity of the reservoir rock and is dimensionless; s is S wi To irreducible water saturation, dimensionless; t (T) o Is the temperature under standard conditions, K; h fr The thickness of the reservoir layer under stratum conditions, m; d, d lc The diameter, m, of a reservoir core under formation conditions; z is Z lr Is the compression factor of the reservoir rock core under laboratory conditions, and has no dimension.
8. The method of predicting the leak pressure of an underground hydrogen storage of claim 7, wherein the diffusion coefficient of hydrogen in the reservoir under laboratory conditions and the diffusion coefficient of hydrogen in the cap layer under laboratory conditions are calculated by the following equations, respectively:
wherein: d (D) fr And D fc Diffusion coefficient of hydrogen in reservoir and cap layer under formation conditions, m 2 S; q is diffusion activation energy, J/mol; r is the gas constant, J/(mol.K).
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