CN117129383A - Device and method for simulating hydrogen water seepage hysteresis rule in hydrogen storage reservoir - Google Patents
Device and method for simulating hydrogen water seepage hysteresis rule in hydrogen storage reservoir Download PDFInfo
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- CN117129383A CN117129383A CN202311066645.0A CN202311066645A CN117129383A CN 117129383 A CN117129383 A CN 117129383A CN 202311066645 A CN202311066645 A CN 202311066645A CN 117129383 A CN117129383 A CN 117129383A
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- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 title claims abstract description 159
- 239000001257 hydrogen Substances 0.000 title claims abstract description 158
- 229910052739 hydrogen Inorganic materials 0.000 title claims abstract description 158
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 109
- 238000003860 storage Methods 0.000 title claims abstract description 53
- 238000000034 method Methods 0.000 title claims abstract description 31
- 239000007789 gas Substances 0.000 claims abstract description 121
- 239000007788 liquid Substances 0.000 claims abstract description 55
- 238000002347 injection Methods 0.000 claims abstract description 36
- 239000007924 injection Substances 0.000 claims abstract description 36
- 239000008398 formation water Substances 0.000 claims abstract description 28
- 238000004519 manufacturing process Methods 0.000 claims abstract description 16
- 230000008569 process Effects 0.000 claims abstract description 12
- 238000001746 injection moulding Methods 0.000 claims abstract description 11
- 238000004088 simulation Methods 0.000 claims abstract description 7
- 239000012530 fluid Substances 0.000 claims description 20
- 239000012071 phase Substances 0.000 claims description 18
- 238000006073 displacement reaction Methods 0.000 claims description 17
- 230000035699 permeability Effects 0.000 claims description 16
- 230000001105 regulatory effect Effects 0.000 claims description 15
- 230000001186 cumulative effect Effects 0.000 claims description 9
- 229920006395 saturated elastomer Polymers 0.000 claims description 9
- 238000002474 experimental method Methods 0.000 claims description 8
- 230000008859 change Effects 0.000 claims description 7
- 238000013022 venting Methods 0.000 claims description 7
- 239000000203 mixture Substances 0.000 claims description 6
- 238000000926 separation method Methods 0.000 claims description 6
- 239000011435 rock Substances 0.000 claims description 5
- 230000015572 biosynthetic process Effects 0.000 claims description 4
- 238000009825 accumulation Methods 0.000 claims description 3
- 239000008346 aqueous phase Substances 0.000 claims description 3
- 239000008367 deionised water Substances 0.000 claims description 3
- 229910021641 deionized water Inorganic materials 0.000 claims description 3
- 238000005553 drilling Methods 0.000 claims description 3
- 238000007789 sealing Methods 0.000 claims description 3
- 238000010438 heat treatment Methods 0.000 claims description 2
- 238000012546 transfer Methods 0.000 description 8
- 238000010926 purge Methods 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical group [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 239000012267 brine Substances 0.000 description 2
- 150000002431 hydrogen Chemical class 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 2
- 230000004075 alteration Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 125000004122 cyclic group Chemical group 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000007599 discharging Methods 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000009977 dual effect Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
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- G—PHYSICS
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- 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
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
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- G09B23/00—Models for scientific, medical, or mathematical purposes, e.g. full-sized devices for demonstration purposes
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- Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
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Abstract
The invention discloses a device and a method for simulating a hydrogen water seepage hysteresis rule in a hydrogen storage reservoir, wherein the device comprises a core clamping unit, a gas injection unit, an injection molding simulated formation water unit and a measuring unit; the core clamping unit comprises a core clamping unit which is connected with a confining pressure pump and a back pressure pump; the gas injection unit comprises a hydrogen cylinder, the hydrogen cylinder is connected with a hydrogen storage tank through a gas booster pump, and the hydrogen storage tank is connected with two ends of the core holder; the injection molding simulated formation water unit comprises a double-cylinder pump and an intermediate container, wherein the upper chamber of the intermediate container is connected with a core holder, and the injection direction is selected through a valve; the measuring unit comprises a first pressure gauge, a second pressure gauge and a gas-liquid separator; both the core holder and the intermediate container are in an incubator. The invention can effectively simulate the processes of circulating multiple hydrogen injection, hydrogen storage and hydrogen collection of the salty water layer and the water-containing depleted gas reservoir type hydrogen storage reservoir, so as to realize the real simulation of the hydrogen and water seepage hysteresis rule in the hydrogen storage reservoir, and provide reference for the adjustment of the injection and production operation mode of the hydrogen storage reservoir.
Description
Technical Field
The invention relates to the field of underground hydrogen storage, in particular to an experimental device and method for simulating a hydrogen and water two-phase seepage hysteresis rule in an underground hydrogen storage reservoir.
Background
The gas-water permeation lag refers to the phenomenon that the relative permeability of gas-water two-phase fluid changes in the process of permeation in rock. The common gas reservoir type underground gas storage is mostly reconstructed from depleted natural gas reservoirs, and after reconstruction, the single-well operation working condition is changed from a depletion type descending exploitation mode of the gas reservoir to a multi-period high-speed injection and exploitation mode of the gas reservoir. The injection and production operation mode exacerbates the complexity of occurrence and flowing state of two-phase fluid in the pore of a reservoir, which can lead to change of fluid seepage characteristics and influence on the storage capacity and injection and production speed of a gas storage. Therefore, experimental simulation research is necessary to carry out on the high-speed injection and production operation mode of the gas storage so as to accurately describe the gas-water distribution of the gas storage layer and predict the operation index of the hydrogen storage.
Disclosure of Invention
Based on the technical problems, the invention provides a device and a method for simulating a hydrogen water seepage hysteresis rule in a hydrogen storage reservoir.
The technical scheme adopted by the invention is as follows:
a device for simulating a hydrogen water seepage hysteresis rule in a hydrogen storage reservoir comprises a core clamping unit, a gas injection unit, an injection molding simulated formation water unit and a measuring unit;
the core clamping unit comprises a core clamping unit used for fixing and sealing a core, and the side surface of the core clamping unit is connected with a confining pressure pump through a confining pressure pipeline;
the gas injection unit comprises a hydrogen cylinder, the hydrogen cylinder is connected with a hydrogen storage tank through a first conveying pipeline, a gas booster pump and a first valve are arranged on the first conveying pipeline, the first conveying pipeline is connected with one end of the core holder through a second conveying pipeline, a second valve, a third valve and a first pressure regulating valve are arranged on the second conveying pipeline, and the first pressure regulating valve is arranged between the second valve and the third valve; the second conveying pipeline is also provided with a first pressure gauge;
the injection molding simulated formation water unit comprises a double-cylinder pump and an intermediate container, wherein a piston is arranged in the intermediate container, the piston divides the internal space of the intermediate container into an upper chamber and a lower chamber, simulated formation water is filled in the upper chamber, and deionized water is filled in the lower chamber; the double-cylinder pump is connected with the lower chamber through a third conveying pipeline, the upper chamber is connected with the other end of the core holder through a fourth conveying pipeline, and a fourth valve is arranged on the fourth conveying pipeline;
the measuring unit comprises a first pressure gauge, a second pressure gauge and a gas-liquid separator, wherein the first pressure gauge is arranged on the second conveying pipeline, and the second pressure gauge is arranged on the fourth conveying pipeline; the fourth conveying pipeline is connected with a gas-liquid separator through a fifth conveying pipeline, the gas-liquid separator is connected with a measuring cylinder through a liquid measuring pipeline, the gas-liquid separator is also connected with a gas pipeline, and a gas flowmeter is arranged on the gas pipeline;
the fifth conveying pipeline is also connected with a return pressure pump through a return pressure pipeline;
a sixth conveying pipeline is further connected between the second conveying pipeline and the fifth conveying pipeline, and a fifth valve is arranged on the sixth conveying pipeline;
a sixth valve and a back pressure valve are arranged on the fifth conveying pipeline, the back pressure pipeline is connected with the back pressure valve, and the connection point of the sixth conveying pipeline and the fifth conveying pipeline is positioned between the sixth valve and the back pressure valve;
the core holder and the intermediate container are both in an incubator.
The gas booster pump is also connected with the air compressor through a seventh conveying pipeline, and a second pressure regulating valve and a second pressure gauge are arranged on the seventh conveying pipeline.
The first conveying pipeline is further provided with a third pressure gauge, the first conveying pipeline is connected with the emptying device through an eighth conveying pipeline, and the eighth conveying pipeline is provided with a seventh valve.
The fourth conveying pipeline is also connected with the second conveying pipeline through a ninth conveying pipeline, and an eighth valve is arranged on the ninth conveying pipeline.
The plurality of intermediate containers are arranged in parallel and form an intermediate container group.
The incubator is also provided with a hydrogen detector for detecting the concentration of hydrogen in the incubator; the incubator is connected with the emptying device through a tenth conveying pipeline.
The two gas flow meters are arranged in parallel; the gas pipeline is also connected with a venting device.
The invention also provides a method for simulating the hydrogen water seepage hysteresis rule in the hydrogen storage reservoir, which adopts the device as described above and comprises the following steps:
step one, taking a target reservoir drilling core, and measuring the length L and the diameter d of the core and the mass m of the dried core;
preparing simulated formation water, taking hydrogen with purity of more than 99.5%, and respectively measuring viscosity mu of the simulated formation water under the reservoir temperature condition w And calculating the hydrogen viscosity μ g ；
Step three, placing the dried rock core into a saturated water device, and vacuumizing saturated stratum water;
step four, connecting the device and debugging, and detecting whether the air tightness of the device and the instrument are normal or not;
loading the core saturated with the formation water in the step three into a core holder, applying confining pressure consistent with the ground stress through a confining pressure pump, and applying back pressure consistent with the formation pressure through a back pressure pump; opening the incubator, heating to the experimental target temperature and keeping the temperature stable;
step six, a hydrogen water driving step;
opening the gas injection unit, closing the injection molding simulated formation water unit, and selecting a proper displacement pressure difference by adjusting the first pressure regulating valve so as to reflect the seepage pressure gradient of the actual reservoir; the pressure of the confining pressure pump is kept unchanged, the first valve, the second valve, the third valve and the sixth valve are opened, and water in the core holder is displaced by hydrogen at constant pressure; the gas-liquid mixture at the outlet of the core holder is conveyed to a gas-liquid separator through a fifth conveying pipeline, gas-liquid separation is carried out in the gas-liquid separator, the separated liquid enters a measuring cylinder through a liquid control pipeline, gas is conveyed through a gas pipeline, and the flow rate is measured through a gas flowmeter;
accurately recording the water yield, the gas yield and the displacement gas flow rate at each moment and the pressure of two ports of the core holder until the hydrogen is driven to a bound water state;
step seven, a hydrogen gas water flooding step;
opening a fourth valve, a fifth valve, closing a second valve, a third valve, a sixth valve and an eighth valve, starting a double-cylinder pump, conveying simulated stratum water in a middle container to a core holder through a fourth conveying pipeline, displacing hydrogen in a core in the core holder, conveying a gas-liquid mixture of the core holder to a gas-liquid separator through the second conveying pipeline, the sixth conveying pipeline and the fifth conveying pipeline in sequence, carrying out gas-liquid separation, enabling separated liquid to enter a measuring cylinder through a liquid control pipeline, conveying gas through a gas pipeline, and conveying the gas through a gas flowmeter;
accurately recording the water yield, the gas yield, the displacement gas flow rate and the pressures of two ports of the core holder at each moment, recording the water injection flow and the pressures of two ports of the core holder until the water drives hydrogen to the saturation of residual gas, and calculating the relative permeability of gas and water phases in the process of unsteady water drives hydrogen;
and step eight, repeating the step six and the step seven, keeping the displacement pressure difference unchanged, and ending the experiment until the phase permeability change rate is less than 3% under the same water saturation.
In the method, the relative permeability of the gas phase and the water phase in the unsteady state hydrogen flooding process is calculated by adopting the following formula:
wherein f w (S g ) The water content is expressed by decimal; mu (mu) w Is the viscosity of formation water, pa.s; mu (mu) g Hydrogen viscosity, pa.s;the fluid volume is produced for dimensionless accumulation, mL; v (V) w (t) is the dimensionless accumulated water yield, mL; />The fluid flow is accumulated for the moment i in a dimensionless way, and the fluid flow is mL; v (V) i-1 (t) is the dimensionless accumulated water yield at the moment i-1, and mL; k (K) rg Is the relative permeability of the gas phase; k (K) rw Relative permeability of the aqueous phase; q (Q) w The water yield is mL/s which is the water yield flowing out from the outlet end at the beginning; q (t) is the water yield flowing out of the outlet end when t, and mL/s; i is relative injection capacity and dimensionless number; s is S g Saturation of gas at the outlet end face; s is S w Saturation for outlet end face water;
since hydrogen has a significant compressibility, a large change in gas volume can be caused by a difference between the inlet pressure and the outlet pressure in the experiment, and thus the cumulative fluid yield needs to be corrected:
wherein V is i Cumulative fluid production, mL, under experimental conditions at time i; v (V) i-1 Cumulative fluid production, mL, under experimental conditions at time i-1; deltaV wi The unit is mL for the increment of water from the i-1 th moment to the i-th moment; p (P) atm Atmospheric pressure, MPa; ΔP is the displacement pressure difference from the i-1 th moment to the i-th moment, and the unit is MPa; deltaV gi The unit is mL, which is the gas increment from the i-1 th moment to the i-th moment measured under the condition of normal temperature and atmospheric pressure; t (T) e The experimental temperature, K; t (T) a Is DeltaV gi And (5) corresponding to normal temperature, K.
In the method, the concentration of the hydrogen in the incubator is detected in real time by the hydrogen detector, and the hydrogen in the incubator, the first conveying pipeline and the gas pipeline is exhausted through the exhausting device when needed.
The beneficial technical effects of the invention are as follows:
the invention can effectively simulate the processes of repeated hydrogen injection, hydrogen storage and hydrogen collection of the salty water layer and the water-containing depleted gas reservoir type hydrogen storage reservoir, and can perform alternate displacement in the forward and reverse directions according to actual conditions, thereby realizing the real simulation of the permeation flow hysteresis rule of the hydrogen and water in the hydrogen storage reservoir and providing reference for the adjustment of the injection and production operation mode of the hydrogen storage reservoir.
The invention also adds a venting device, which can timely vent the trace hydrogen possibly accumulated in the incubator, the gas injection unit and the like, so as to improve the operation safety of the whole experimental device.
Drawings
The invention is further described with reference to the drawings and detailed description which follow:
FIG. 1 is a schematic diagram of the structure principle of the device for simulating the hydrogen and water seepage hysteresis law in a hydrogen storage library;
FIG. 2 is a schematic flow chart of the method for simulating the law of hydrogen and water seepage in a hydrogen storage library.
In the figure: the device comprises a core holder, a 2-confining pressure pipeline, a 3-confining pressure pump, a 4-hydrogen cylinder, a 5-first conveying pipeline, a 6-hydrogen storage tank, a 7-gas booster pump, an 8-first valve, a 9-second conveying pipeline, a 10-second valve, a 11-third valve, a 12-first pressure regulating valve, a 13-first pressure gauge, a 14-double cylinder pump, a 15-intermediate container, a 16-third conveying pipeline, a 17-fourth conveying pipeline, a 18-fourth valve, a 19-first pressure gauge, a 20-second pressure gauge, a 21-gas-liquid separator, a 22-fifth conveying pipeline, a 23-gas pipeline, a 24-gas flowmeter, a 25-back pressure pipeline, a 26-back pressure pump, a 27-sixth conveying pipeline, a 28-fifth valve, a 29-sixth valve, a 30-back pressure valve, a 31-constant temperature box, a 32-seventh conveying pipeline, a 33-air compressor, a 34-second pressure regulating valve, a 35-second pressure gauge, a 36-third pressure gauge, a 37-eighth conveying pipeline, a 38-seventh conveying valve, a 39-eighth conveying pipeline, a 39-ninth conveying pipeline, a 40-ninth conveying pipeline, a fourth pressure gauge, a 45-ninth pressure gauge, a buffer device and a 45-fourth conveying pipeline, a 45-fourth pressure gauge, a buffer device and a 45-fourth conveying pipeline, and a buffer device.
Detailed Description
With reference to the attached drawings, the device for simulating the hydrogen and water seepage hysteresis law in the underground hydrogen storage reservoir comprises a core clamping unit, a gas injection unit, an injection molding simulated formation water unit and a measuring unit. The core clamping unit comprises a core clamping unit 1 for fixing and sealing a core, and the side surface of the core clamping unit 1 is connected with a confining pressure pump 3 through a confining pressure pipeline 2. The gas injection unit comprises a hydrogen cylinder 4, the hydrogen cylinder 4 is connected with a hydrogen storage tank 6 through a first conveying pipeline 5, and a gas booster pump 7 and a first valve 8 are arranged on the first conveying pipeline 5. The first conveying pipeline 5 is connected with one end of the core holder 1 through a second conveying pipeline 9, a second valve 10, a third valve 11 and a first pressure regulating valve 12 are arranged on the second conveying pipeline 9, and the first pressure regulating valve 12 is arranged between the second valve 10 and the third valve 11. A first pressure gauge 13 is also provided on the second delivery conduit 9, the first pressure gauge 13 being used to observe the inlet gas pressure of the core holder 1. The injection molding simulated formation water unit comprises a double pump 14 and an intermediate container 15, wherein a piston is arranged in the intermediate container 15, the piston divides the internal space of the intermediate container into an upper chamber and a lower chamber, simulated formation water is filled in the upper chamber, and deionized water is filled in the lower chamber. The double pump 14 is connected with the lower chamber through a third conveying pipeline 16, the upper chamber is connected with the other end of the core holder 1 through a fourth conveying pipeline 17, and a fourth valve 18 is arranged on the fourth conveying pipeline 17. The measuring unit comprises a first pressure gauge 19, a second pressure gauge 20 and a gas-liquid separator 21, the first pressure gauge 19 being mounted on the second conveying pipe 9, the second pressure gauge 20 being mounted on the fourth conveying pipe 17. The fourth conveying pipeline 17 is connected with a gas-liquid separator 21 through a fifth conveying pipeline 22, the gas-liquid separator 21 is connected with a measuring cylinder 44 through a liquid measuring pipeline, the gas-liquid separator is also connected with a gas pipeline 23, and a gas flowmeter 24 is arranged on the gas pipeline 23. The fifth feed line 22 is also connected to a return pressure pump 26 via a return pressure line 25. A sixth conveying pipeline 27 is also connected between the second conveying pipeline 9 and the fifth conveying pipeline 22, and a fifth valve 28 is arranged on the sixth conveying pipeline 27. A sixth valve 29 and a back pressure valve 30 are provided on the fifth transfer duct 22, the back pressure duct 25 is connected to the back pressure valve 30, and the connection point of the sixth transfer duct 27 and the fifth transfer duct 22 is between the sixth valve 29 and the back pressure valve 30. Both the core holder 1 and the intermediate container 15 are in an incubator 31.
The first pressure gauge 19 and the second pressure gauge 20 are used for monitoring the inlet pressure and the outlet pressure of the core holder 1, respectively. The gas-liquid separator 21 separates liquid and gas by gravity, liquid is measured by the measuring cylinder 44, gas is measured by the gas flowmeter 24, the gas flowmeter 24 is provided with two measuring ranges respectively, and a proper flowmeter can be selected according to actual conditions.
According to the invention, the gas injection unit, the injection simulated water unit and the like are arranged, and the units are orderly connected through the pipelines, so that the processes of repeated hydrogen injection, hydrogen storage and hydrogen production of the salty water layer hydrogen storage library can be effectively simulated, alternate displacement in the forward and reverse directions can be performed according to actual situations, the real simulation of the permeation flow hysteresis rule of hydrogen and water in the hydrogen storage library is realized, and a reference is provided for the adjustment of the injection and production operation mode of the hydrogen storage library.
As a further design of the present invention, the gas booster pump 7 is further connected to an air compressor 33 via a seventh conveying pipe 32, and a second pressure regulating valve 34 and a second pressure gauge 35 are provided in the seventh conveying pipe 32. The invention firstly pressurizes the hydrogen in the hydrogen cylinder through the gas booster pump 7, then stores the hydrogen in the hydrogen storage tank 6, and then provides hydrogen with stable pressure for the core holder 1 through the hydrogen storage tank 6.
The hydrogen bottle 4 is used for storing hydrogen needed by experiments, and is stored in a dark place and a cool place, and the pressure is detected at fixed time. Since the pressure of the gas in the hydrogen cylinder may not meet the experimental requirements, a gas booster pump 7 or the like is provided for increasing the hydrogen pressure. Wherein, the gas booster pump 7 and the air compressor 33 increase the pressure for hydrogen; the first 13, second 35, first 12 and second 34 pressure regulating valves are used to monitor and control pressure, respectively. The hydrogen tank 6 is used for storing the pressurized hydrogen gas.
Further, a third pressure gauge 36 is provided on the first transfer pipe 5, the first transfer pipe 5 is connected to the evacuation device 43 through an eighth transfer pipe 37, and a seventh valve 38 is provided on the eighth transfer pipe 37. The first delivery pipe may be purged with hydrogen gas or the like at a proper timing by the purge device 43, or the hydrogen storage tank 6 may be purged with gas.
Further, the fourth conveying pipe 17 is further connected to the second conveying pipe 9 through a ninth conveying pipe 39, and an eighth valve 40 is provided on the ninth conveying pipe 39. By connecting the fourth conveying pipeline 17 with the second conveying pipeline 9, the liquid injection direction of the core holder 1 can be controlled and switched through a valve according to actual simulation requirements.
Further, a plurality of intermediate containers 15 are arranged in parallel with each other to form an intermediate container group. One or more of the intermediate containers may be activated according to actual needs. Each intermediate container is provided with a valve and a vent pipeline, the valve controls the opening and closing of the intermediate container and the vent pipeline, and the vent pipeline is used for discharging residual gas in the intermediate container. The dual pump 32 is used to drive the liquid in the intermediate container.
Further, the incubator 31 is further provided with a hydrogen detector 41 for detecting the hydrogen concentration in the incubator. The incubator 31 is connected to a venting device 43 via a tenth transfer conduit 42. The hydrogen concentration in the incubator 31 can be detected in real time by the hydrogen detector 41, and timely emptied by the emptying device 43, so that the safety of the whole simulation experiment device is improved.
Further, two gas flow meters 24 are provided, and the two gas flow meters 24 are arranged in parallel. The gas pipe 23 is also connected to a venting device 43. The venting means 43 open to the outside for venting the hydrogen escaping from the gas injection unit, the incubator, the gas line.
The back pressure pump 26 can set back pressure, and the back pressure pump 3 is matched to enable the core holder 1 to keep high pressure. A buffer vessel 45, a fourth pressure gauge 46 and a ninth valve 47 are provided on the back pressure line 25. The buffer container 45 can stabilize the pressure.
The incubator 31 is used to set the temperature of the core holder 1, and can simulate the actual reservoir temperature.
The hydrogen detector 41 is used to monitor whether hydrogen escapes from the incubator 31.
The pipeline, the valve and the like are all made of hydrogen-resistant materials.
The invention also provides a method for simulating the hydrogen and water seepage hysteresis law in the hydrogen storage library, which adopts the device as described above and comprises the following steps:
step one, taking a target reservoir drilling core, and measuring the length L and the diameter d of the core and the mass m of the dried core. Specifically, representative rock samples should be selected, drilled to have a diameter of 3.80cm or 2.50cm and a length not less than 1.5 times the diameter, and to ensure measurement accuracy, the core is measured multiple times at different positions by using a vernier caliper, and an average value is obtained under the condition that the relative error is not more than 5%.
Preparing simulated formation water, taking hydrogen with purity of more than 99.5%, and respectively measuring viscosity mu of the simulated formation water under the reservoir temperature condition w And calculating the hydrogen viscosity μ g 。
Specifically, formation water viscosity may be determined by capillary methods and hydrogen viscosity may be calculated using the Sagnac equation. The simulated formation water can be sodium chloride solution with the molar concentration of 15%, and can be prepared according to actual conditions.
And thirdly, placing the dried rock core into a saturated water device to vacuumize saturated stratum water.
And fourthly, connecting the device and debugging, and detecting whether the air tightness of the device and the instrument are normal.
And fifthly, loading the core saturated with the formation water in the step three into the core holder 1, applying confining pressure consistent with the ground stress through the confining pressure pump 3, and applying back pressure consistent with the formation pressure through the back pressure pump 26. The oven 31 was opened, warmed to the experimental target temperature and kept stable.
Step six, a hydrogen water driving step;
opening the gas injection unit, closing the injection molding simulated formation water unit, and selecting a proper displacement pressure difference by adjusting the first pressure regulating valve so as to reflect the seepage pressure gradient of the actual reservoir; the pressure of the confining pressure pump is kept unchanged, the first valve, the second valve, the third valve and the sixth valve are opened, and water in the core holder is displaced by hydrogen at constant pressure; the gas-liquid mixture at the outlet of the core holder is conveyed to a gas-liquid separator through a fifth conveying pipeline, gas-liquid separation is carried out in the gas-liquid separator, the separated liquid enters a measuring cylinder through a liquid control pipeline, gas is conveyed through a gas pipeline, and the flow rate is measured through a gas flowmeter;
accurately recording the water yield, the gas yield and the displacement gas flow rate at each moment and the pressure of two ports of the core holder until the hydrogen is driven to a bound water state;
step seven, a hydrogen gas water flooding step;
opening a fourth valve, a fifth valve, closing a second valve, a third valve, a sixth valve and an eighth valve, starting a double-cylinder pump, conveying simulated stratum water in a middle container to a core holder through a fourth conveying pipeline, displacing hydrogen in a core in the core holder, conveying a gas-liquid mixture of the core holder to a gas-liquid separator through the second conveying pipeline, the sixth conveying pipeline and the fifth conveying pipeline in sequence, carrying out gas-liquid separation, enabling separated liquid to enter a measuring cylinder through a liquid control pipeline, conveying gas through a gas pipeline, and conveying the gas through a gas flowmeter;
accurately recording the water yield, the gas yield, the displacement gas flow rate and the pressures of two ports of the core holder at each moment, recording the water injection flow and the pressures of two ports of the core holder until the water drives hydrogen to the saturation of residual gas, and calculating the relative permeability of gas and water phases in the process of unsteady water drives hydrogen;
and step eight, repeating the step six and the step seven, keeping the displacement pressure difference unchanged, and ending the experiment until the phase permeability change rate is less than 3% under the same water saturation.
The invention can better simulate the cyclic injection and production process of the hydrogen in the salty water layer hydrogen storage warehouse, and accurately reveal the hydrogen and water seepage lag rule in the hydrogen storage warehouse.
In the method, the relative permeability of the gas phase and the water phase in the unsteady state hydrogen flooding process is calculated by adopting the following formula:
wherein f w (S g ) The water content is expressed by decimal; mu (mu) w Is the viscosity of formation water, pa.s; mu (mu) g Hydrogen viscosity, pa.s;the fluid volume is produced for dimensionless accumulation, mL; v (V) w (t) is the dimensionless accumulated water yield, mL; v (V) i t is the dimensionless accumulated produced fluid quantity at the moment i, and mL; v (V) i-1 (t) is the dimensionless accumulated water yield at the moment i-1, and mL; k (K) rg Is the relative permeability of the gas phase; k (K) rw Relative permeability of the aqueous phase; q (Q) w The water yield is mL/s which is the water yield flowing out from the outlet end at the beginning; q (t) is the water yield flowing out of the outlet end when t, and mL/s; i is relative injection capacity and dimensionless number; s is S g Saturation of gas at the outlet end face; s is S w Is the water saturation of the outlet end face.
Since hydrogen has a significant compressibility, a large change in gas volume can be caused by a difference between the inlet pressure and the outlet pressure in the experiment, and thus the cumulative fluid yield needs to be corrected:
wherein V is i Cumulative fluid production, mL, under experimental conditions at time i; v (V) i-1 Cumulative fluid production, mL, under experimental conditions at time i-1; deltaV wi The unit is mL for the increment of water from the i-1 th moment to the i-th moment; p (P) atm Atmospheric pressure, MPa; ΔP is the displacement pressure difference from the i-1 th moment to the i-th moment, and the unit is MPa; deltaV gi The unit is mL, which is the gas increment from the i-1 th moment to the i-th moment measured under the condition of normal temperature and atmospheric pressure; t (T) e The experimental temperature, K; t (T) a Is DeltaV gi And (5) corresponding to normal temperature, K.
In the above method, the concentration of hydrogen in the incubator 31 is detected in real time by the hydrogen detector 41, and the hydrogen in the incubator 31, the first delivery pipe 5, and the gas pipe 23 is purged by a purge device as needed.
In the method, the confining pressure pump 3 is used for setting confining pressure of the core holder 1, so that formation pressure in actual conditions can be simulated. It should be noted that the inlet pressure of the core holder 1 is at least 1.5Mpa lower than the confining pressure of the core holder, otherwise the core holder will have a cross-over pressure.
In the method, after the experiment is finished, nitrogen is required to purge the device, and the hydrogen in the device is discharged.
The device and the method can better simulate the gas flooding (gas injection) process and the water flooding (gas production) process when the brine layer stores hydrogen, further can effectively simulate the hydrogen and water seepage hysteresis rule in the hydrogen storage, and provide reference for the brine layer hydrogen storage multi-injection and production process.
The parts not described in the above modes can be realized by adopting or referring to the prior art.
Although embodiments of the present invention have been shown and described, it will be understood by those skilled in the art that various changes, modifications, substitutions and alterations can be made therein without departing from the principles and spirit of the invention, the scope of which is defined in the appended claims and their equivalents.
Claims (10)
1. The utility model provides a device of hydrogen water seepage flow hysteresis law in simulation hydrogen storage storehouse reservoir which characterized in that: the device comprises a core clamping unit, a gas injection unit, an injection molding simulated formation water unit and a measuring unit;
the core clamping unit comprises a core clamping unit used for fixing and sealing a core, and the side surface of the core clamping unit is connected with a confining pressure pump through a confining pressure pipeline;
the gas injection unit comprises a hydrogen cylinder, the hydrogen cylinder is connected with a hydrogen storage tank through a first conveying pipeline, a gas booster pump and a first valve are arranged on the first conveying pipeline, the first conveying pipeline is connected with one end of the core holder through a second conveying pipeline, a second valve, a third valve and a first pressure regulating valve are arranged on the second conveying pipeline, and the first pressure regulating valve is arranged between the second valve and the third valve; the second conveying pipeline is also provided with a first pressure gauge;
the injection molding simulated formation water unit comprises a double-cylinder pump and an intermediate container, wherein a piston is arranged in the intermediate container, the piston divides the internal space of the intermediate container into an upper chamber and a lower chamber, simulated formation water is filled in the upper chamber, and deionized water is filled in the lower chamber; the double-cylinder pump is connected with the lower chamber through a third conveying pipeline, the upper chamber is connected with the other end of the core holder through a fourth conveying pipeline, and a fourth valve is arranged on the fourth conveying pipeline;
the measuring unit comprises a first pressure gauge, a second pressure gauge and a gas-liquid separator, wherein the first pressure gauge is arranged on the second conveying pipeline, and the second pressure gauge is arranged on the fourth conveying pipeline; the fourth conveying pipeline is connected with a gas-liquid separator through a fifth conveying pipeline, the gas-liquid separator is connected with a measuring cylinder through a liquid measuring pipeline, the gas-liquid separator is also connected with a gas pipeline, and a gas flowmeter is arranged on the gas pipeline;
the fifth conveying pipeline is also connected with a return pressure pump through a return pressure pipeline;
a sixth conveying pipeline is further connected between the second conveying pipeline and the fifth conveying pipeline, and a fifth valve is arranged on the sixth conveying pipeline;
a sixth valve and a back pressure valve are arranged on the fifth conveying pipeline, the back pressure pipeline is connected with the back pressure valve, and the connection point of the sixth conveying pipeline and the fifth conveying pipeline is positioned between the sixth valve and the back pressure valve;
the core holder and the intermediate container are both in an incubator.
2. The apparatus for simulating a hydrogen water seepage hysteresis law in a hydrogen storage reservoir of claim 1, wherein: the gas booster pump is also connected with the air compressor through a seventh conveying pipeline, and a second pressure regulating valve and a second pressure gauge are arranged on the seventh conveying pipeline.
3. The apparatus for simulating a hydrogen water seepage hysteresis law in a hydrogen storage reservoir of claim 1, wherein: the first conveying pipeline is further provided with a third pressure gauge, the first conveying pipeline is connected with the emptying device through an eighth conveying pipeline, and the eighth conveying pipeline is provided with a seventh valve.
4. The apparatus for simulating a hydrogen water seepage hysteresis law in a hydrogen storage reservoir of claim 1, wherein: the fourth conveying pipeline is also connected with the second conveying pipeline through a ninth conveying pipeline, and an eighth valve is arranged on the ninth conveying pipeline.
5. The apparatus for simulating a hydrogen water seepage hysteresis law in a hydrogen storage reservoir of claim 1, wherein: the intermediate containers are arranged in a plurality of parallel and form an intermediate container group.
6. The apparatus for simulating a hydrogen water seepage hysteresis law in a hydrogen storage reservoir of claim 1, wherein: the constant temperature box is also provided with a hydrogen detector for detecting the concentration of hydrogen in the constant temperature box; the incubator is connected with the emptying device through a tenth conveying pipeline.
7. The apparatus for simulating a hydrogen water seepage hysteresis law in a hydrogen storage reservoir of claim 1, wherein: the two gas flow meters are arranged in parallel; the gas pipeline is also connected with a venting device.
8. A method for simulating the law of hydrogen water seepage in a hydrogen storage reservoir, using the device according to any one of claims 1 to 7, characterized by comprising the steps of:
step one, taking a target reservoir drilling core, and measuring the length L and the diameter d of the core and the mass m of the dried core;
preparing simulated formation water, taking hydrogen with purity of more than 99.5%, and respectively measuring viscosity mu of the simulated formation water under the reservoir temperature condition w And calculating the hydrogen viscosity μ g ；
Step three, placing the dried rock core into a saturated water device, and vacuumizing saturated stratum water;
step four, connecting the device and debugging, and detecting whether the air tightness of the device and the instrument are normal or not;
loading the core saturated with the formation water in the step three into a core holder, applying confining pressure consistent with the ground stress through a confining pressure pump, and applying back pressure consistent with the formation pressure through a back pressure pump; opening the incubator, heating to the experimental target temperature and keeping the temperature stable;
step six, a hydrogen water driving step;
opening the gas injection unit, closing the injection molding simulated formation water unit, and selecting a proper displacement pressure difference by adjusting the first pressure regulating valve so as to reflect the seepage pressure gradient of the actual reservoir; the pressure of the confining pressure pump is kept unchanged, the first valve, the second valve, the third valve and the sixth valve are opened, and water in the core holder is displaced by hydrogen at constant pressure; the gas-liquid mixture at the outlet of the core holder is conveyed to a gas-liquid separator through a fifth conveying pipeline, gas-liquid separation is carried out in the gas-liquid separator, the separated liquid enters a measuring cylinder through a liquid control pipeline, gas is conveyed through a gas pipeline, and the flow rate is measured through a gas flowmeter;
accurately recording the water yield, the gas yield and the displacement gas flow rate at each moment and the pressure of two ports of the core holder until the hydrogen is driven to a bound water state;
step seven, a hydrogen gas water flooding step;
opening a fourth valve, a fifth valve, closing a second valve, a third valve, a sixth valve and an eighth valve, starting a double-cylinder pump, conveying simulated stratum water in a middle container to a core holder through a fourth conveying pipeline, displacing hydrogen in a core in the core holder, conveying a gas-liquid mixture of the core holder to a gas-liquid separator through the second conveying pipeline, the sixth conveying pipeline and the fifth conveying pipeline in sequence, carrying out gas-liquid separation, enabling separated liquid to enter a measuring cylinder through a liquid control pipeline, conveying gas through a gas pipeline, and conveying the gas through a gas flowmeter;
accurately recording the water yield, the gas yield, the displacement gas flow rate and the pressures of two ports of the core holder at each moment, recording the water injection flow and the pressures of two ports of the core holder until the water drives hydrogen to the saturation of residual gas, and calculating the relative permeability of gas and water phases in the process of unsteady water drives hydrogen;
and step eight, repeating the step six and the step seven, keeping the displacement pressure difference unchanged, and ending the experiment until the phase permeability change rate is less than 3% under the same water saturation.
9. A method of modeling hydrogen water seepage hysteresis law in a hydrogen storage reservoir according to claim 8, wherein: the relative permeability of the gas phase and the water phase in the unsteady state hydrogen flooding process is calculated by adopting the following formula:
wherein f w (S g ) The water content is expressed by decimal; mu (mu) w Is the viscosity of formation water, pa.s; mu (mu) g Hydrogen viscosity, pa.s;the fluid volume is produced for dimensionless accumulation, mL; v (V) w (t) is the dimensionless accumulated water yield, mL; />The fluid flow is accumulated for the moment i in a dimensionless way, and the fluid flow is mL; v (V) i-1 (t) is the dimensionless accumulated water yield at the moment i-1, and mL; k (K) rg Is the relative permeability of the gas phase; k (K) rw Relative permeability of the aqueous phase; q (Q) w The water yield is mL/s which is the water yield flowing out from the outlet end at the beginning; q (t) is the water yield flowing out of the outlet end when t, and mL/s; i is relative injection capacity and dimensionless number; s is S g Saturation of gas at the outlet end face; s is S w Saturation for outlet end face water;
since hydrogen has a significant compressibility, a large change in gas volume can be caused by a difference between the inlet pressure and the outlet pressure in the experiment, and thus the cumulative fluid yield needs to be corrected:
wherein V is i Cumulative fluid production, mL, under experimental conditions at time i; v (V) i-1 Cumulative fluid production, mL, under experimental conditions at time i-1; deltaV wi The unit is mL for the increment of water from the i-1 th moment to the i-th moment; p (P) atm Atmospheric pressure, MPa; ΔP is the displacement pressure difference from the i-1 th moment to the i-th moment, and the unit is MPa; deltaV gi The unit is mL, which is the gas increment from the i-1 th moment to the i-th moment measured under the condition of normal temperature and atmospheric pressure; t (T) e The experimental temperature, K; t (T) a Is DeltaV gi And (5) corresponding to normal temperature, K.
10. A method of modeling hydrogen water seepage hysteresis law in a hydrogen storage reservoir according to claim 8, wherein:
the concentration of the hydrogen in the incubator is detected in real time by the hydrogen detector, and the hydrogen in the incubator, the first conveying pipeline and the gas pipeline is exhausted through the exhausting device when needed.
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN117949615A (en) * | 2024-03-27 | 2024-04-30 | 中国石油大学(华东) | Experimental device and experimental method for separating components of flue gas in aquifer |
| CN117993228A (en) * | 2024-04-03 | 2024-05-07 | 西南石油大学 | Injection and production phase seepage hysteresis analysis method and equipment for fracture-cavity type gas storage and storage medium |
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Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117949615A (en) * | 2024-03-27 | 2024-04-30 | 中国石油大学(华东) | Experimental device and experimental method for separating components of flue gas in aquifer |
| CN117949615B (en) * | 2024-03-27 | 2024-06-07 | 中国石油大学(华东) | Experimental device and experimental method for separating components of flue gas in aquifer |
| CN117993228A (en) * | 2024-04-03 | 2024-05-07 | 西南石油大学 | Injection and production phase seepage hysteresis analysis method and equipment for fracture-cavity type gas storage and storage medium |
| CN117993228B (en) * | 2024-04-03 | 2024-05-31 | 西南石油大学 | Injection and production phase seepage hysteresis analysis method and equipment for fracture-cavity type gas storage and storage medium |
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