CN116539815A - Device and method suitable for evaluating and optimizing working fluid of oil and gas reservoir - Google Patents
Device and method suitable for evaluating and optimizing working fluid of oil and gas reservoir Download PDFInfo
- Publication number
- CN116539815A CN116539815A CN202310669088.5A CN202310669088A CN116539815A CN 116539815 A CN116539815 A CN 116539815A CN 202310669088 A CN202310669088 A CN 202310669088A CN 116539815 A CN116539815 A CN 116539815A
- Authority
- CN
- China
- Prior art keywords
- pressure
- core
- oil
- control valve
- nuclear magnetic
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 239000012530 fluid Substances 0.000 title claims abstract description 104
- 238000000034 method Methods 0.000 title claims abstract description 43
- 238000002347 injection Methods 0.000 claims abstract description 39
- 239000007924 injection Substances 0.000 claims abstract description 39
- 238000012360 testing method Methods 0.000 claims abstract description 39
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 17
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 17
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 17
- 239000003921 oil Substances 0.000 claims description 68
- 230000035699 permeability Effects 0.000 claims description 47
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 40
- 238000005481 NMR spectroscopy Methods 0.000 claims description 35
- 229920006395 saturated elastomer Polymers 0.000 claims description 30
- 238000004519 manufacturing process Methods 0.000 claims description 29
- 239000011435 rock Substances 0.000 claims description 29
- 238000002474 experimental method Methods 0.000 claims description 18
- 239000007788 liquid Substances 0.000 claims description 18
- 238000006073 displacement reaction Methods 0.000 claims description 17
- 230000015572 biosynthetic process Effects 0.000 claims description 14
- 238000001035 drying Methods 0.000 claims description 14
- 230000006378 damage Effects 0.000 claims description 13
- 239000011521 glass Substances 0.000 claims description 12
- PWHULOQIROXLJO-UHFFFAOYSA-N Manganese Chemical compound [Mn] PWHULOQIROXLJO-UHFFFAOYSA-N 0.000 claims description 11
- 230000008859 change Effects 0.000 claims description 11
- 229910052748 manganese Inorganic materials 0.000 claims description 11
- 239000011572 manganese Substances 0.000 claims description 11
- 238000001228 spectrum Methods 0.000 claims description 11
- 230000005311 nuclear magnetism Effects 0.000 claims description 10
- 150000002696 manganese Chemical class 0.000 claims description 9
- 239000010779 crude oil Substances 0.000 claims description 8
- 239000011148 porous material Substances 0.000 claims description 7
- 239000012224 working solution Substances 0.000 claims description 7
- 238000005553 drilling Methods 0.000 claims description 6
- 238000001816 cooling Methods 0.000 claims description 4
- 229920001971 elastomer Polymers 0.000 claims description 4
- 230000002431 foraging effect Effects 0.000 claims description 4
- 238000007781 pre-processing Methods 0.000 claims description 4
- 238000012545 processing Methods 0.000 claims description 4
- 239000002699 waste material Substances 0.000 claims description 4
- 238000004458 analytical method Methods 0.000 claims description 3
- 101150117004 atg18 gene Proteins 0.000 claims description 3
- 238000007789 sealing Methods 0.000 claims description 3
- 235000013547 stew Nutrition 0.000 claims description 3
- 230000008569 process Effects 0.000 abstract description 19
- 238000011156 evaluation Methods 0.000 abstract description 15
- 230000035945 sensitivity Effects 0.000 abstract description 9
- 238000005457 optimization Methods 0.000 abstract description 5
- 239000007789 gas Substances 0.000 description 48
- 238000009472 formulation Methods 0.000 description 7
- 239000000203 mixture Substances 0.000 description 7
- 238000004364 calculation method Methods 0.000 description 4
- 238000011161 development Methods 0.000 description 4
- 230000018109 developmental process Effects 0.000 description 4
- 238000010276 construction Methods 0.000 description 3
- 238000009826 distribution Methods 0.000 description 3
- 230000001105 regulatory effect Effects 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 230000001808 coupling effect Effects 0.000 description 2
- 230000007547 defect Effects 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000007246 mechanism Effects 0.000 description 2
- 230000020477 pH reduction Effects 0.000 description 2
- 230000006641 stabilisation Effects 0.000 description 2
- 238000011105 stabilization Methods 0.000 description 2
- YCKRFDGAMUMZLT-UHFFFAOYSA-N Fluorine atom Chemical compound [F] YCKRFDGAMUMZLT-UHFFFAOYSA-N 0.000 description 1
- 229910021380 Manganese Chloride Inorganic materials 0.000 description 1
- GLFNIEUTAYBVOC-UHFFFAOYSA-L Manganese chloride Chemical compound Cl[Mn]Cl GLFNIEUTAYBVOC-UHFFFAOYSA-L 0.000 description 1
- 208000027418 Wounds and injury Diseases 0.000 description 1
- 230000032683 aging Effects 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 239000011737 fluorine Substances 0.000 description 1
- 229910052731 fluorine Inorganic materials 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 239000001257 hydrogen Substances 0.000 description 1
- 229910052739 hydrogen Inorganic materials 0.000 description 1
- 125000004435 hydrogen atom Chemical group [H]* 0.000 description 1
- 208000014674 injury Diseases 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 239000011565 manganese chloride Substances 0.000 description 1
- 229940099607 manganese chloride Drugs 0.000 description 1
- 235000002867 manganese chloride Nutrition 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 235000010755 mineral Nutrition 0.000 description 1
- 238000000655 nuclear magnetic resonance spectrum Methods 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
Classifications
-
- 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
-
- 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
- G01N33/24—Earth materials
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A90/00—Technologies having an indirect contribution to adaptation to climate change
- Y02A90/30—Assessment of water resources
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Health & Medical Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Biochemistry (AREA)
- Immunology (AREA)
- Physics & Mathematics (AREA)
- Analytical Chemistry (AREA)
- Food Science & Technology (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Medicinal Chemistry (AREA)
- Pathology (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Remote Sensing (AREA)
- Testing Of Devices, Machine Parts, Or Other Structures Thereof (AREA)
Abstract
The invention provides a device and a method suitable for evaluating and optimizing a working fluid of a hydrocarbon reservoir, wherein the method comprises the following steps: the system comprises a fluid injection system, a vacuumizing system, an online testing system and a metering system, wherein the fluid injection system, the vacuumizing system and the metering system are respectively connected with the online testing system. The device and the method for evaluating and optimizing the working fluid of the oil and gas reservoir, provided by the invention, have the advantages of simple structure, convenience in connection and operation, more close to the actual field in the experimental process, and the influence of speed sensitivity on the experimental result is avoided, and the accuracy of the evaluation and optimization of the working fluid is improved.
Description
Technical Field
The invention relates to the technical field of oil and gas development experiments, in particular to an experimental method and device suitable for evaluating and optimizing working fluid of an oil and gas reservoir.
Background
Drilling, well cementation, well completion, perforation, well workover, water injection, acidification and fracturing until tertiary oil recovery are performed in each construction process link in the exploration and development process of the oil and gas field, and the reservoir involves injection working fluid including drilling fluid, well completion fluid, perforation fluid, acidification fluid, injection water, well control fluid, fracturing fluid and the like. If working fluid enters a reservoir, various physical and chemical actions can occur when the working fluid is not matched with the mineral or fluid in the reservoir, so that the reservoir is damaged, and the exploitation efficiency is affected.
The damage evaluation of the domestic working fluid mainly adopts a standard SY/T5358-2010, the existing industry standard is mainly suitable for rock samples with permeability greater than 1mD, the pore structure of a hypotonic reservoir is complex, the damage of a compact reservoir is difficult to evaluate, the method can only evaluate and optimize from a single index of permeability, the stable flow time of fluid is too long when the permeability is tested, the damage process of the working fluid to the reservoir under the underground actual working condition cannot be simulated after the experimental process is simplified, and the problems of large measurement error, high time cost, high requirement on experimental instruments and the like are caused, so that the experimental accuracy is affected. It is therefore necessary to devise a device and method suitable for evaluating and optimizing hydrocarbon reservoir fluids.
Disclosure of Invention
The invention aims to provide a device and a method suitable for evaluating and optimizing working fluid of a hydrocarbon reservoir, the device has a simple structure, is convenient to connect and operate, the experimental process is closer to the field reality, the influence of speed sensitivity on the experimental result is avoided, and the accuracy of the evaluation and optimization of the working fluid is improved.
In order to achieve the above object, the present invention provides the following solutions:
an apparatus for evaluating and optimizing a hydrocarbon reservoir fluid, comprising: the system comprises a fluid injection system, a vacuumizing system, an online test system and a metering system, wherein the fluid injection system, the vacuumizing system and the metering system are respectively connected with the online test system;
the on-line testing system comprises a nuclear magnetic on-line detector, a clamp holder, a confining pressure system, a first pressure sensor, a second pressure sensor, a first six-way valve, a second six-way valve, a back pressure automatic tracking pump and a data acquisition system, wherein the clamp holder is arranged in the nuclear magnetic on-line detector, the middle part of the clamp holder is connected with the confining pressure system, two ends of the clamp holder are connected with the first six-way valve and the second six-way valve, the first six-way valve is respectively connected with the fluid injection system, the vacuumizing system, the first pressure sensor and the second six-way valve, the second six-way valve is respectively connected with the vacuumizing system, the back pressure valve, the back pressure automatic tracking pump and the second pressure sensor, the back pressure automatic tracking pump is connected with the back pressure valve, the back pressure valve is connected with the metering system, and the first pressure sensor, the second pressure sensor, the nuclear magnetic on-line detector and the metering system are respectively connected with the data acquisition system.
Optionally, the fluid injection system includes a constant-speed constant-pressure pump, a first four-way joint, a second four-way joint, a first control valve, a second control valve, a third control valve, a fourth control valve, a fifth control valve, a sixth control valve, an injection system intermediate container, a manganese water intermediate container and an oil-gas intermediate container, wherein the constant-speed constant-pressure pump is connected with the first four-way joint, the first four-way joint is respectively connected with the first control valve, the second control valve and the third control valve, the first control valve is connected with the injection system intermediate container, the second control valve is connected with the manganese water intermediate container, the third control valve is connected with the oil-gas intermediate container, the injection system intermediate container is connected with the fourth control valve, the manganese water intermediate container is connected with the fifth control valve, the oil-gas intermediate container is connected with the sixth control valve, the fourth control valve, the fifth control valve and the sixth control valve are respectively connected with the second joint, and the second joint is connected with the first six-way valve.
Optionally, the vacuum pumping system includes vacuum pressure gauge, third four-way connection, drying pipe and vacuum pump, the vacuum pump is connected the drying pipe, the drying pipe is connected the third four-way connection, the third four-way connection is connected respectively first six-way valve, second six-way valve and vacuum pressure gauge.
Optionally, the metering system includes oil water separator and gas flowmeter, oil water separator comprises test tube and the glass bottle of taking the plug, the test tube is upright to be fixed the glass bottle bottom, the test tube is connected the back pressure pump, the glass bottle is connected gas flowmeter, gas flowmeter connects data acquisition system.
The method for evaluating and optimizing the working fluid of the oil and gas reservoirs, which is applied to any device suitable for evaluating and optimizing the working fluid of the oil and gas reservoirs, is characterized by comprising the following steps of:
step 1: selecting a target reservoir rock, processing the selected reservoir rock into a standard plunger sample, preprocessing the processed plunger sample, arranging the preprocessed plunger sample in a holder, and preparing fluid required by an experiment;
step 2: vacuumizing the core, pressurizing saturated manganese water, pressurizing and displacing saturated oil, establishing a saturated oil state of bound water, calculating the saturation of oil-bearing gas, measuring an initial nuclear magnetic resonance T2 map, obtaining the effective porosity of the core, and calculating the permeability through the effective porosity of the core;
step 3: simulating formation temperature and pressure conditions, pressurizing and injecting working fluid, sealing a well for aging, giving production pressure difference, recording oil gas yield and liquid yield, and measuring a nuclear magnetic resonance T2 map after the production is finished;
step 4: repeatedly pressurizing and displacing saturated crude oil, and carrying out last nuclear magnetic scanning T2 map after saturation is completed, and calculating nuclear magnetic permeability again;
step 5: and (3) replacing parallel samples, carrying out repeated tests of working fluids with different formulas, and comparing and evaluating the damage degree of the working fluids according to the nuclear magnetism T2 spectrum, wherein the working fluid is optimized by taking the oil displacement efficiency as a standard.
Optionally, in step 1, selecting a target reservoir rock, processing the selected reservoir rock into a standard plunger sample, preprocessing the processed plunger sample, setting the preprocessed plunger sample in the holder, and preparing fluid required by an experiment, wherein the fluid is specifically as follows: selecting rock blocks required by experiments, drilling a plurality of core column parallel samples with the diameter of 25mm, drying the rock samples to constant weight, taking out the core, placing the core in a cooler, cooling to room temperature, testing the length and the diameter of the core for later use, and preparing working liquid required by the experiments.
Optionally, in step 2, the core is vacuumized and pressurized with saturated manganese water, then saturated oil is pressurized and displaced, a saturated oil state of the bound water is established, the pore volume and the oil-gas saturation of the core are calculated, and an initial nuclear magnetic resonance T2 map is measured, specifically:
step 201: placing the rock core into a holder, applying a certain confining pressure to the holder, vacuumizing the rock core, and after vacuumizing, raising the confining pressure to the overburden pressure P Surrounding wall Pressurizing saturated manganese water by using the actual pressure P of the reservoir, decompressing after saturation is completed, pressurizing and displacing saturated crude oil gas by using a step-by-step boosting mode until the outlet end is no longer discharged to reach a water-limited saturated oil gas state, and recording the injection quantity V 1 And the liquid discharge amount V 2 Calculating the saturation of oil and gas;
step 202: and according to the formation temperature and pressure, lifting back pressure to reservoir pressure P, lifting the test system to the formation temperature and pressure condition by oiling gas pressurization, waiting for the system to be stable, measuring a nuclear magnetic resonance T2 map, and calculating the effective porosity and permeability of the core.
Optionally, in step 3, simulating the formation temperature and pressure condition, pressurizing and injecting the working solution, ageing the well, giving out production pressure difference, recording oil gas yield and liquid yield, and measuring a nuclear magnetic resonance T2 map after the production is finished, wherein the method specifically comprises the following steps:
step 301: reference site actual injection pressure P 1 Injecting working fluid from one end of the core at constant pressure, and simultaneously raising back pressure to P+P 1 To the pressure P+P at the two ends of the core 1 When stable, closing the inlet valve of the clamp holder to stew the well for 12 hours, setting the back pressure automatic tracking pump pressure difference as the production pressure difference, gradually reducing the back pressure until the waste pressure is reached to stop production, and metering the oil output, the gas output and the liquid output at different moments by a metering system;
step 302: and after the production is finished, performing nuclear magnetic resonance scanning, testing a nuclear magnetic resonance T2 map, and decompressing.
The nuclear magnetic permeability of the core and the change rate of the nuclear magnetic permeability of the core are calculated by adopting an SDR model in the field of nuclear magnetic resonance core analysis and well logging, and the formula is as follows:
wherein K is NMR For nuclear magnetic permeability, T 2g For the geometric mean of the relaxation time, phi is the effective porosity of the core, ai is the amplitude of the ith point,is T 2 -an i-th relaxation time in the amplitude coordinate system;
the change rate of the core nuclear magnetic permeability caused by the contact of the working solution and the core is expressed as the following formula:
wherein D represents the change rate of core nuclear magnetic permeability and K NMR0 Represents the core permeability, K, of the core after initial saturation NMR1 Representing the nuclear magnetic permeability of the core after the production is finished and the repeated pressurization displacement is saturated.
According to the specific embodiment provided by the invention, the invention discloses the following technical effects: the device and the method are suitable for reservoir evaluation of various permeability levels, and make up for the defects of the existing reservoir working fluid evaluation method; the experimental process is designed to be closer to the actual conditions of the site, so that the damage mechanism and process of the working fluid to the reservoir under the actual working condition can be simulated; according to the invention, the reservoir damage is evaluated, the oil displacement efficiency of the working fluid is considered, and the evaluation and optimization accuracy is improved; different oil-water distribution characteristics, different pore throat utilization degrees and fluid occurrence conditions can be analyzed in the construction throughput process of the simulated working fluid, so that theoretical support is provided for subsequent development work; the test time is greatly shortened aiming at the hypotonic reservoir stratum, and the experimental efficiency is improved; and the occurrence of reservoir sensitivity coupling effect caused by speed sensitivity is eliminated in the working solution evaluation experiment process.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions of the prior art, the drawings that are needed in the embodiments will be briefly described below, it being obvious that the drawings in the following description are only some embodiments of the present invention, and that other drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a schematic diagram of an embodiment of the present invention;
FIG. 2 is a flow chart of a method according to an embodiment of the invention;
FIG. 3 is a graph showing the results of displacement efficiency using two formulations according to an embodiment of the present invention;
FIG. 4 is a chart of a nuclear magnetic resonance T2 spectrum of the working fluid of formula 1 according to an embodiment of the present invention;
FIG. 5 is a chart of a T2 nuclear magnetic resonance spectrum using the working fluid of formulation 2 in an embodiment of the present invention;
FIG. 6 is a graph showing the ratio of permeabilities before and after the use of two formulations in accordance with an embodiment of the present invention.
Reference numerals: 1, injecting into a system intermediate container; 2. a manganese water intermediate container; 3. an oil gas intermediate container; 4. a second four-way joint; 5. a fourth control valve; 6. a fifth control valve; 7. a sixth control valve; 8. a first control valve; 9. a second control valve; 10. a third control valve; 11. a first four-way joint; 12. constant speed constant pressure pump; 13. a first pressure sensor; 14. a first six-way valve; 15. a nuclear magnetic online detector; 16. a holder; 17. a confining pressure system; 18. a vacuum pressure gauge; 19. a third four-way joint; 20. a drying tube; 21. a vacuum pump; 22. a second pressure sensor; 23. a second six-way valve; 24. a back pressure valve; 25. a data acquisition system; 26. back pressure automatic tracking pump; 27. a test tube; 28. a glass bottle; 29. an oil-gas-water separator; 30. a gas flow meter.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
The invention aims to provide the device and the method which are suitable for evaluating and optimizing the working fluid of the oil and gas reservoir, and the device and the method are simple in structure, convenient to connect and operate, and more close to the field reality in the experimental process, avoid the influence of speed sensitivity on the experimental result, and improve the accuracy of the evaluation and optimization of the working fluid.
In order that the above-recited objects, features and advantages of the present invention will become more readily apparent, a more particular description of the invention will be rendered by reference to the appended drawings and appended detailed description.
As shown in fig. 1, an apparatus for evaluating and optimizing a working fluid for a hydrocarbon reservoir includes: the system comprises a fluid injection system, a vacuumizing system, an online test system and a metering system, wherein the fluid injection system, the vacuumizing system and the metering system are respectively connected with the online test system;
the on-line test system comprises a nuclear magnetism on-line detector 15, a clamp holder 16, a confining pressure system 17, a first pressure sensor 13, a second pressure sensor 22, a first six-way valve 14, a second six-way valve 23, a back pressure valve 24, a back pressure automatic tracking pump 26 and a data acquisition system 25, wherein the clamp holder 16 is arranged in the nuclear magnetism on-line detector 15, the middle part of the clamp holder 16 is connected with the confining pressure system 17, two ends of the clamp holder 16 are connected with the first six-way valve 14 and the second six-way valve 23, the first six-way valve 14 is respectively connected with the fluid injection system, the vacuumizing system, the first pressure sensor 13 and the second six-way valve 23, the second six-way valve 23 is respectively connected with the vacuumizing system, the back pressure valve 24, the back pressure automatic tracking pump 26 and the second pressure sensor 22, the back pressure automatic tracking pump 26 is connected with the back pressure valve 24, the back pressure valve 24 is connected with the metering system, and the first pressure sensor 13, the second pressure sensor 22, the nuclear magnetism detector 15 and the data acquisition system are respectively connected with the on-line system 25. The nuclear magnetic online detector 15 is high-temperature and high-pressure resistant, the confining pressure system 17 has a heating function, liquid used by the confining pressure pump in the confining pressure system 17 is fluorine oil, and the tracking pressure of the back pressure automatic tracking pump 26 is determined according to the actual production pressure difference of a reservoir.
The fluid injection system comprises a constant-speed constant-pressure pump 12, a first four-way joint 11, a second four-way joint 4, a first control valve 8, a second control valve 9, a third control valve 10, a fourth control valve 5, a fifth control valve 6, a sixth control valve 7, an injection system intermediate container 1, a manganese water intermediate container 2 and an oil gas intermediate container 3, wherein the constant-speed constant-pressure pump 12 is connected with the first four-way joint 11, the first four-way joint 11 is respectively connected with the first control valve 8, the second control valve 9 and the third control valve 10, the first control valve 8 is connected with the injection system intermediate container 1, the second control valve 9 is connected with the manganese water intermediate container 2, the third control valve 10 is connected with the oil gas intermediate container 3, the injection system intermediate container 1 is connected with the fourth control valve 5, the manganese water intermediate container 2 is connected with the fifth control valve 6, the oil gas intermediate container 3 is connected with the sixth control valve 7, and the fourth control valve 5, the fifth control valve 6 and the sixth control valve 7 are respectively connected with the fourth four-way joint 4 and the fourth four-way joint 14 is connected with the fourth four-way joint 4.
The vacuumizing system comprises a vacuum pressure gauge 18, a third four-way joint 19, a drying pipe 20 and a vacuum pump 21, wherein the vacuum pump 21 is connected with the drying pipe 20, the drying pipe 20 is connected with the third four-way joint 19, and the third four-way joint 19 is respectively connected with the first six-way valve 14, the second six-way valve 23 and the vacuum pressure gauge 18.
The metering system comprises an oil-water separator and a gas flowmeter 30, wherein the oil-water separator consists of a test tube 27 with a rubber plug and a glass bottle 28, the test tube 27 is vertically fixed at the bottom of the glass bottle 28, the test tube 27 is connected with the back pressure pump, the glass bottle 28 is connected with the gas flowmeter 30, and the gas flowmeter 30 is connected with the data acquisition system 25. The test tube 27 is provided with a rubber plug and scales, the glass bottle 28 is provided with the rubber plug, and the volume of the glass bottle 28 is not easy to be excessively large, so that the delay of gas metering is avoided.
As shown in fig. 2, a method for evaluating and optimizing a working fluid for a hydrocarbon reservoir, which is applied to any one of the above devices for evaluating and optimizing a working fluid for a hydrocarbon reservoir, comprises the following steps:
step 1: selecting a target reservoir rock, processing the selected reservoir rock into a standard plunger sample, preprocessing the processed plunger sample, arranging the preprocessed plunger sample in the holder 16, and preparing fluid required by an experiment;
step 2: vacuumizing the core, pressurizing saturated manganese water, pressurizing and displacing saturated oil, establishing a saturated oil state of bound water, calculating the saturation of oil-bearing gas, measuring an initial nuclear magnetic resonance T2 map, obtaining the effective porosity of the core, and calculating the permeability through the effective porosity of the core;
step 3: simulating formation temperature and pressure conditions, pressurizing and injecting working fluid, sealing a well for aging, giving production pressure difference, recording oil gas yield and liquid yield, and measuring a nuclear magnetic resonance T2 map after the production is finished;
step 4: repeatedly pressurizing and displacing saturated crude oil, and carrying out last nuclear magnetic scanning T2 map after saturation is completed, and calculating nuclear magnetic permeability again;
step 5: and (3) replacing parallel samples, carrying out repeated tests of working fluids with different formulas, and comparing and evaluating the damage degree of the working fluids according to the nuclear magnetism T2 spectrum, wherein the working fluid is optimized by taking the oil displacement efficiency as a standard.
In step 1, a target reservoir rock is selected, the selected reservoir rock is processed into a standard plunger sample, the processed plunger sample is preprocessed, the preprocessed plunger sample is arranged in a clamp 16, and fluid required by experiments is prepared, specifically: selecting rock blocks required by experiments, drilling a plurality of core column parallel samples with the diameter of 25mm, drying the rock samples to constant weight, taking out the core, placing the core in a cooler, cooling to room temperature, testing the length and the diameter of the core for later use, and preparing working liquid required by the experiments.
In the step 2, the core is vacuumized and pressurized to saturate the manganese water, then saturated oil is pressurized and displaced, a saturated oil state of the restrained water is established, the pore volume and the oil-gas saturation of the core are calculated, and an initial nuclear magnetic resonance T2 map is measured, wherein the method specifically comprises the following steps:
step 201: placing the core into a holder 16, applying a certain confining pressure to the holder 16, vacuumizing the core, and raising the confining pressure to the overburden pressure P after vacuumizing Surrounding wall Pressurizing saturated manganese water by using the actual pressure P of the reservoir, decompressing after saturation is completed, pressurizing and displacing saturated crude oil gas by using a step-by-step boosting mode until the outlet end is no longer discharged to reach a water-limited saturated oil gas state, and recording the injection quantity V 1 And the liquid discharge amount V 2 Calculating the saturation of oil and gas;
step 202: and according to the formation temperature and pressure, lifting back pressure to reservoir pressure P, lifting the test system to the formation temperature and pressure condition by oiling gas pressurization, waiting for the system to be stable, measuring a nuclear magnetic resonance T2 map, and calculating the effective porosity and permeability of the core.
In the step 3, the formation temperature and pressure conditions are simulated, the working fluid is pressurized and injected, the well is closed for aging, the production pressure difference is given, the oil gas output and the liquid output are recorded, and the nuclear magnetic resonance T2 map after the production is finished is measured, specifically:
step 301: reference site actual injection pressure P 1 Injecting working fluid from one end of the core at constant pressure, and simultaneously raising back pressure to P+P 1 To the pressure P+P at the two ends of the core 1 When stable, closing the inlet valve of the clamp holder 16 to stew the well for 12 hours, setting the pressure difference of the back pressure automatic tracking pump 26 as the production pressure difference, gradually reducing the back pressure until the waste pressure is reached to stop production, and metering the oil output, the gas output and the liquid output at different moments by the metering system;
step 302: and after the production is finished, performing nuclear magnetic resonance scanning, testing a nuclear magnetic resonance T2 map, and decompressing.
The nuclear magnetic permeability of the core and the change rate of the nuclear magnetic permeability of the core are calculated by adopting an SDR model in the field of nuclear magnetic resonance core analysis and well logging, and the formula is as follows:
wherein K is NMR For nuclear magnetic permeability, T 2g For the geometric mean of the relaxation time, phi is the effective porosity of the core, ai is the amplitude of the ith point,is T 2 -an i-th relaxation time in the amplitude coordinate system;
the change rate of the core nuclear magnetic permeability caused by the contact of the working solution and the core is expressed as the following formula:
wherein D represents the change rate of core nuclear magnetic permeability and K NMR0 Represents the core permeability, K, of the core after initial saturation NMR1 Representing the nuclear magnetic permeability of the core after the production is finished and the repeated pressurization displacement is saturated.
The integral area of T2 curve distribution can be regarded as nuclear magnetic porosity by utilizing a T2 map inverted by nuclear magnetic resonance, the step simulates the actual saturated oil bound water state of a reservoir, and the effective porosity of nuclear magnetism is bound fluid porosity+movable fluid porosity, bound water is not movable and nuclear magnetism is not collected, so that the movable fluid porosity is the effective porosity of the reservoir because the used manganese chloride solution can not collect hydrogen signals and can only collect oil signals in the pores of the reservoir.
Aiming at the technical scheme, the embodiment of the invention provides the following experimental steps:
step 1: selecting compact sandstone rock blocks, drilling a plurality of core column parallel samples with the diameter of 25mm and the height of 50mm, drying the core sample to constant weight at 100 ℃ after oil washing, taking out the core, placing the core into a cooler, cooling to room temperature, testing the length and diameter of the core for later use, and configuring a formula 1 fracturing fluid and a formula 2 fracturing fluid required by an experiment;
step 2: placing the rock core into a holder 16, adjusting a confining pressure system 17, applying certain confining pressure to the rock core holder 16, starting a vacuum pump 21, opening corresponding valves on a first six-way valve 14 and a second six-way valve 23, which are connected with a vacuumizing system, vacuumizing the rock core, and closing corresponding valves on the first six-way valve 14 and the second six-way valve 23, which are connected with the vacuumizing system, after vacuumizing is finished;
step 3: adjusting the confining pressure system 17 to raise the confining pressure to the overburden pressure P Surrounding wall Is 30MP a Closing corresponding valves connected with a vacuumizing system on the first six-way valve 14 and the second six-way valve 23, opening corresponding valves connected with a fluid injection system and the clamp 16, opening the second control valve 9 and the fifth control valve 6, adjusting the constant-speed constant-pressure pump 12, pressurizing saturated manganese water from two ends of the clamp 16 for 12 hours with the actual reservoir pressure P of 20MPa, adjusting the constant-speed constant-pressure pump 12 to reduce the system pressure to normal pressure of 0MPa after saturation is completed, closing the second control valve 9 and the fifth control valve 6, and closing corresponding valves of connecting pipelines of the first six-way valve 14 and the second six-way valve 23;
step 4: opening and controlling the third control valve 10 and the sixth control valve 7, regulating the constant-speed constant-pressure pump 12, pressurizing and displacing the saturated crude oil gas in a step-by-step pressure increasing mode until the outlet end of the back pressure valve 24 is no longer discharged to reach a water-saturated oil gas binding state, and recording the injection quantity V of the constant-speed constant-pressure pump 12 1 And the discharge amount V at the outlet end of the back pressure valve 24 2 Calculation of oil and gas saturation calculation of oil saturation 100 (V 1 -V 2 )/V 1 ；
Step 5: according to the formation temperature pressure of 70 ℃ and 20MPa, regulating a back pressure automatic tracking pump 26, lifting the pressure of a back pressure valve 24 to 20MPa of reservoir pressure P, regulating a constant speed constant pressure pump 12 and a confining pressure system 17, lifting an online test system to the formation temperature pressure condition by oiling gas pressurization, waiting for the system to be stable, measuring a nuclear magnetic resonance T2 map, calculating the effective porosity and permeability of a rock core, and obtaining the initial permeability of 0.0136mD by calculation;
step 6: reference site actual injection pressure P 1 27MPa, closing the third control valve 10 and the sixth control valve 7, opening the first control valve 8 and the fourth control valve 5, adjusting the constant-speed constant-pressure pump 12, injecting the fracturing fluid of the formula 1 from the left end of the clamp holder 16 at a constant pressure of 27MPa, and simultaneously lifting the pressure of the back pressure valve 24 to be P+P 1 27MPa to the pressure P+P at the two ends of the core 1 When stable, closing a corresponding valve on the first six-way valve 14 at the inlet of the clamp holder 16, and stewing the well for 12h;
step 7: setting a back pressure automatic tracking pump 26, namely, in a tracking mode, tracking the pressure at the outlet end of the clamp 16, wherein the tracking pressure difference is 3MPa of production pressure difference, gradually reducing the back pressure to start production until the back pressure reaches 10MPa of waste pressure, stopping production, and measuring the oil output, the gas output and the liquid output of the oil-gas-water separator 29 and the gas flowmeter 30 at different moments;
step 8: after the production is finished, nuclear magnetic scanning is carried out, a nuclear magnetic resonance T2 map is tested, and the system pressure is relieved to be in a normal pressure state;
step 9: 4, re-pressurizing and displacing saturated crude oil gas, performing nuclear magnetic scanning T2 atlas after saturation is completed, and calculating rock permeability to be 0.0104mD;
step 10: and (3) replacing the parallel sample to perform a formula 2 working solution evaluation experiment, repeating the steps 1-9, and measuring the initial permeability of the parallel sample to be 0.0139mD and the permeability after reaction to be 0.0109mD.
Fig. 3 is a graph showing the results of oil displacement efficiency using two formulations, fig. 4 is a graph showing the nuclear magnetic resonance T2 spectrum using the working fluid of formulation 1, fig. 5 is a graph showing the nuclear magnetic resonance T2 spectrum using the working fluid of formulation 2, and fig. 6 is a graph showing the ratio of permeability before and after injection using two formulations.
From the aspect of oil displacement efficiency, the oil displacement efficiency shows a gradual trend after increasing along with time, and the oil displacement efficiency of the fracturing fluid in the formula 1 is 10.56 percent which is far greater than that in the formula 2 by 7.39 percent; as can be seen by comparing nuclear magnetic resonance (nmr) T2 spectra before and after the injection, the change trend of the throughput nmr T2 spectra of the two cores is basically the same under the corresponding fracturing fluid formula, and the oil produced in the sample throughput process corresponding to formula 1 is more, and the greatest decrease of the nmr T2 spectra is shown, which is consistent with the oil displacement efficiency result; as can be seen by comparing nuclear magnetic resonance T2 spectra of saturated oil before and after the injection, the saturated oil graph curve after the injection moves leftwards, and the peak value on the right side is reduced, which indicates that damage occurs to the reservoir, and the damage is the same as the change result of the permeability ratio; if the SY/T5358-2010 evaluation standard is referred, the fracturing fluid of the formula 2 is preferable, but the fracturing fluid of the formula 1 is more suitable for a reservoir at the place according to the evaluation of oil displacement effect.
The permeability is measured by the calculated liquid in the reference standard, the displacement stabilization process of the hypotonic reservoir is very slow when the permeability is calculated, and the test time is shortened by using the nuclear magnetism to calculate the permeability without the stabilization process of the outlet end. In the reservoir injury evaluation, if the displacement speed is too high, the conventional method can cause the speed sensitivity in the seepage process, and the scheme adopts saturation in the permeability evaluation, and the speed sensitivity cannot be caused by using nuclear magnetism calculation.
By combining the above, the device and the method provided by the invention are suitable for evaluating and optimizing the working fluid of the oil and gas reservoir, are suitable for evaluating reservoirs with various permeability levels, and make up for the defects of the existing evaluating method of the working fluid of the reservoirs; the experimental process is designed to be closer to the actual conditions of the site, so that the damage mechanism and process of the working fluid to the reservoir under the actual working condition can be simulated; according to the invention, the reservoir damage is evaluated, the oil displacement efficiency of the working fluid is considered, and the evaluation and optimization accuracy is improved; different oil-water distribution characteristics, different pore throat utilization degrees and fluid occurrence conditions can be analyzed in the construction throughput process of the simulated working fluid, so that theoretical support is provided for subsequent development work; the test time is greatly shortened aiming at the hypotonic reservoir stratum, and the experimental efficiency is improved; and the occurrence of reservoir sensitivity coupling effect caused by speed sensitivity is eliminated in the working solution evaluation experiment process.
The principles and embodiments of the present invention have been described herein with reference to specific examples, the description of which is intended only to assist in understanding the methods of the present invention and the core ideas thereof; also, it is within the scope of the present invention to be modified by those of ordinary skill in the art in light of the present teachings. In view of the foregoing, this description should not be construed as limiting the invention.
Claims (9)
1. An apparatus for evaluating and optimizing a hydrocarbon reservoir fluid, comprising: the system comprises a fluid injection system, a vacuumizing system, an online test system and a metering system, wherein the fluid injection system, the vacuumizing system and the metering system are respectively connected with the online test system;
the on-line testing system comprises a nuclear magnetic on-line detector, a clamp holder, a confining pressure system, a first pressure sensor, a second pressure sensor, a first six-way valve, a second six-way valve, a back pressure automatic tracking pump and a data acquisition system, wherein the clamp holder is arranged in the nuclear magnetic on-line detector, the middle part of the clamp holder is connected with the confining pressure system, two ends of the clamp holder are connected with the first six-way valve and the second six-way valve, the first six-way valve is respectively connected with the fluid injection system, the vacuumizing system, the first pressure sensor and the second six-way valve, the second six-way valve is respectively connected with the vacuumizing system, the back pressure valve, the back pressure automatic tracking pump and the second pressure sensor, the back pressure automatic tracking pump is connected with the back pressure valve, the back pressure valve is connected with the metering system, and the first pressure sensor, the second pressure sensor, the nuclear magnetic on-line detector and the metering system are respectively connected with the data acquisition system.
2. The device for evaluating and optimizing a working fluid for a hydrocarbon reservoir according to claim 1, wherein the fluid injection system comprises a constant-speed constant-pressure pump, a first four-way joint, a second four-way joint, a first control valve, a second control valve, a third control valve, a fourth control valve, a fifth control valve, a sixth control valve, an injection system intermediate container, a manganese water intermediate container and an oil-gas intermediate container, the constant-speed constant-pressure pump is connected to the first four-way joint, the first four-way joint is connected to the first control valve, the second control valve and the third control valve, the first control valve is connected to the injection system intermediate container, the second control valve is connected to the manganese water intermediate container, the third control valve is connected to the oil-gas intermediate container, the injection system intermediate container is connected to the fourth control valve, the manganese water intermediate container is connected to the fifth control valve, the oil-gas intermediate container is connected to the sixth control valve, the fourth control valve, the fifth control valve and the sixth control valve are connected to the fourth four-way joint, respectively, and the second control valve is connected to the fourth four-way joint and the fourth joint is connected to the fourth four-way joint.
3. The device for evaluating and optimizing a working fluid for a hydrocarbon reservoir according to claim 1, wherein the vacuumizing system comprises a vacuum pressure gauge, a third four-way joint, a drying pipe and a vacuum pump, the vacuum pump is connected with the drying pipe, the drying pipe is connected with the third four-way joint, and the third four-way joint is respectively connected with the first six-way valve, the second six-way valve and the vacuum pressure gauge.
4. The device for evaluating and optimizing the working fluid of the oil and gas reservoir according to claim 1, wherein the metering system comprises an oil-water separator and a gas flowmeter, the oil-water separator consists of a test tube with a rubber plug and a glass bottle, the test tube is vertically fixed at the bottom of the glass bottle, the test tube is connected with the back pressure pump, the glass bottle is connected with the gas flowmeter, and the gas flowmeter is connected with the data acquisition system.
5. A method for evaluating and optimizing a hydrocarbon reservoir working fluid, applied to the device for evaluating and optimizing a hydrocarbon reservoir working fluid according to any one of claims 1 to 4, characterized by comprising the steps of:
step 1: selecting a target reservoir rock, processing the selected reservoir rock into a standard plunger sample, preprocessing the processed plunger sample, arranging the preprocessed plunger sample in a holder, and preparing fluid required by an experiment;
step 2: vacuumizing the core, pressurizing saturated manganese water, pressurizing and displacing saturated oil, establishing a saturated oil state of bound water, calculating the saturation of oil-bearing gas, measuring an initial nuclear magnetic resonance T2 map, obtaining the effective porosity of the core, and calculating the permeability through the effective porosity of the core;
step 3: simulating formation temperature and pressure conditions, pressurizing and injecting working fluid, sealing a well for aging, giving production pressure difference, recording oil gas yield and liquid yield, and measuring a nuclear magnetic resonance T2 map after the production is finished;
step 4: repeatedly pressurizing and displacing saturated crude oil, and carrying out last nuclear magnetic scanning T2 map after saturation is completed, and calculating nuclear magnetic permeability again;
step 5: and (3) replacing parallel samples, carrying out repeated tests of working fluids with different formulas, and comparing and evaluating the damage degree of the working fluids according to the nuclear magnetism T2 spectrum, wherein the working fluid is optimized by taking the oil displacement efficiency as a standard.
6. The method for evaluating and optimizing a hydrocarbon reservoir fluid according to claim 5, wherein in step 1, a target reservoir rock is selected, the selected reservoir rock is processed into a standard plunger sample, the processed plunger sample is pretreated, the pretreated plunger sample is arranged in a holder, and fluid required for experiments is prepared, specifically: selecting rock blocks required by experiments, drilling a plurality of core column parallel samples with the diameter of 25mm, drying the rock samples to constant weight, taking out the core, placing the core in a cooler, cooling to room temperature, testing the length and the diameter of the core for later use, and preparing working liquid required by the experiments.
7. The method for evaluating and optimizing a hydrocarbon reservoir working fluid according to claim 5, wherein in step 2, the core is vacuumized, pressurized with saturated manganese water, then saturated oil is displaced under pressure, a bound water saturated oil state is established, the pore volume of the core and the saturation of hydrocarbon content are calculated, and an initial nuclear magnetic resonance T2 map is measured, specifically:
step 201: placing the rock core into a holder, applying a certain confining pressure to the holder, vacuumizing the rock core, and after vacuumizing, raising the confining pressure to the overburden pressure P Surrounding wall Pressurizing saturated manganese water by using the actual pressure P of the reservoir, decompressing after saturation is completed, pressurizing and displacing saturated crude oil gas by using a step-by-step boosting mode until the outlet end is no longer discharged to reach a water-saturated oil gas stateThe injection quantity V is recorded 1 And the liquid discharge amount V 2 Calculating the saturation of oil and gas;
step 202: and according to the formation temperature and pressure, lifting back pressure to reservoir pressure P, lifting the test system to the formation temperature and pressure condition by oiling gas pressurization, waiting for the system to be stable, measuring a nuclear magnetic resonance T2 map, and calculating the effective porosity and permeability of the core.
8. The method for evaluating and optimizing a working fluid for a hydrocarbon reservoir according to claim 5, wherein in step 3, the formation temperature and pressure conditions are simulated, the working fluid is pressurized and injected and aged in a well, the production pressure difference is given, the oil gas yield and the liquid yield are recorded, and the nuclear magnetic resonance T2 spectrum after the production is finished is measured, specifically:
step 301: reference site actual injection pressure P 1 Injecting working fluid from one end of the core at constant pressure, and simultaneously raising back pressure to P+P 1 To the pressure P+P at the two ends of the core 1 When stable, closing the inlet valve of the clamp holder to stew the well for 12 hours, setting the back pressure automatic tracking pump pressure difference as the production pressure difference, gradually reducing the back pressure until the waste pressure is reached to stop production, and metering the oil output, the gas output and the liquid output at different moments by a metering system;
step 302: and after the production is finished, performing nuclear magnetic resonance scanning, testing a nuclear magnetic resonance T2 map, and decompressing.
9. The method for evaluating and optimizing a working fluid for a hydrocarbon reservoir according to claim 7, wherein the nuclear magnetic permeability of the core and the rate of change of the nuclear magnetic permeability of the core are calculated by using an SDR model in the field of nuclear magnetic resonance core analysis and logging, and the formula is:
wherein K is NMR For nuclear magnetic permeability, T 2g For the geometric mean of the relaxation time, phi is the effective porosity of the core, ai is the amplitude of the ith point,is T 2 -an i-th relaxation time in the amplitude coordinate system;
the change rate of the core nuclear magnetic permeability caused by the contact of the working solution and the core is expressed as the following formula:
wherein D represents the change rate of core nuclear magnetic permeability and K NMR0 Represents the core permeability, K, of the core after initial saturation NMR1 Representing the nuclear magnetic permeability of the core after the production is finished and the repeated pressurization displacement is saturated.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310669088.5A CN116539815B (en) | 2023-06-07 | 2023-06-07 | Device and method suitable for evaluating and optimizing working fluid of oil and gas reservoir |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202310669088.5A CN116539815B (en) | 2023-06-07 | 2023-06-07 | Device and method suitable for evaluating and optimizing working fluid of oil and gas reservoir |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN116539815A true CN116539815A (en) | 2023-08-04 |
| CN116539815B CN116539815B (en) | 2024-03-19 |
Family
ID=87450782
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202310669088.5A Active CN116539815B (en) | 2023-06-07 | 2023-06-07 | Device and method suitable for evaluating and optimizing working fluid of oil and gas reservoir |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN116539815B (en) |
Citations (10)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102323394A (en) * | 2011-08-23 | 2012-01-18 | 中国地质大学（武汉） | Experimental apparatus and method for researching response characteristic of natural gas hydrate stratum to drilling fluid intrusion |
| CN103091346A (en) * | 2013-01-18 | 2013-05-08 | 上海大学 | Rock core displacement effect visual evaluation method |
| CN107894386A (en) * | 2017-11-14 | 2018-04-10 | 西安石油大学 | The quantitative evaluation method that supercritical carbon dioxide injection influences on low permeability sandstone reservoir pore throat character |
| CN109239119A (en) * | 2018-09-14 | 2019-01-18 | 重庆科技学院 | A method of tight sandstone reservoir stress sensitive is evaluated based on nuclear magnetic resonance technique |
| CN109709131A (en) * | 2018-11-20 | 2019-05-03 | 中国石油天然气股份有限公司 | Compact oil core huff-puff experimental method, device and system |
| CN113834762A (en) * | 2020-06-24 | 2021-12-24 | 中国石油化工股份有限公司 | Method and system for measuring gas-water relative permeability curve |
| CN216978762U (en) * | 2022-03-09 | 2022-07-15 | 四川省科源工程技术测试中心 | Core fluid quantitative saturation-displacement device |
| CN115372398A (en) * | 2022-07-19 | 2022-11-22 | 东北石油大学 | Novel method for quantitatively evaluating sensitivity of shale oil and gas reservoir to foreign fluid |
| CN115389387A (en) * | 2021-05-24 | 2022-11-25 | 中国石油化工股份有限公司 | Experimental method for evaluating rock core damage |
| CN115788373A (en) * | 2021-11-26 | 2023-03-14 | 中国石油天然气集团有限公司 | CO (carbon monoxide) 2 Evaluation method for oil-gas displacement rule of shale oil reservoir |
-
2023
- 2023-06-07 CN CN202310669088.5A patent/CN116539815B/en active Active
Patent Citations (10)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102323394A (en) * | 2011-08-23 | 2012-01-18 | 中国地质大学（武汉） | Experimental apparatus and method for researching response characteristic of natural gas hydrate stratum to drilling fluid intrusion |
| CN103091346A (en) * | 2013-01-18 | 2013-05-08 | 上海大学 | Rock core displacement effect visual evaluation method |
| CN107894386A (en) * | 2017-11-14 | 2018-04-10 | 西安石油大学 | The quantitative evaluation method that supercritical carbon dioxide injection influences on low permeability sandstone reservoir pore throat character |
| CN109239119A (en) * | 2018-09-14 | 2019-01-18 | 重庆科技学院 | A method of tight sandstone reservoir stress sensitive is evaluated based on nuclear magnetic resonance technique |
| CN109709131A (en) * | 2018-11-20 | 2019-05-03 | 中国石油天然气股份有限公司 | Compact oil core huff-puff experimental method, device and system |
| CN113834762A (en) * | 2020-06-24 | 2021-12-24 | 中国石油化工股份有限公司 | Method and system for measuring gas-water relative permeability curve |
| CN115389387A (en) * | 2021-05-24 | 2022-11-25 | 中国石油化工股份有限公司 | Experimental method for evaluating rock core damage |
| CN115788373A (en) * | 2021-11-26 | 2023-03-14 | 中国石油天然气集团有限公司 | CO (carbon monoxide) 2 Evaluation method for oil-gas displacement rule of shale oil reservoir |
| CN216978762U (en) * | 2022-03-09 | 2022-07-15 | 四川省科源工程技术测试中心 | Core fluid quantitative saturation-displacement device |
| CN115372398A (en) * | 2022-07-19 | 2022-11-22 | 东北石油大学 | Novel method for quantitatively evaluating sensitivity of shale oil and gas reservoir to foreign fluid |
Non-Patent Citations (1)
| Title |
|---|
| 国家能源局 发布: "SY/T 5358-2010 储层敏感性流动实验评价方法", 中华人民共和国石油天然气行业标准, pages 1 - 32 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN116539815B (en) | 2024-03-19 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN106596380B (en) | Shale staged fracturing horizontal well fracturing fluid flowback capability evaluation method and device | |
| CN110296921B (en) | Testing device and testing method for shale gas permeability under reservoir conditions in steady state method | |
| WO2019095800A1 (en) | Fracture conductivity assessment device and method based on gas-liquid two-phase flow in shale fractures | |
| CN111257202A (en) | Shale fracturing fluid forced imbibition and flowback experimental method under condition of containing adsorbed gas | |
| US5263360A (en) | Low permeability subterranean formation testing methods and apparatus | |
| CN102608011B (en) | Method for determining and building bound water for crack-pore (hole) type reservoir core | |
| CN106198338A (en) | Shale reservoir fracturing fracture stress sensitivity testing device and method using same | |
| CN112459760A (en) | Carbon dioxide energy storage composite fracturing experimental device | |
| CN102455277A (en) | Device and method for measuring gasometry permeability of rock under high pressure | |
| CN110261274B (en) | Evaluation method for static contribution rate of spontaneous imbibition effect on water flooding oil displacement efficiency | |
| CN104101564A (en) | Device and method for testing low-permeability core starting pressure gradient at high temperature and high pressure with unsteady state method | |
| CN112798494B (en) | Long core drying seepage experimental device and experimental method | |
| CN108827830B (en) | Device and method for testing flow performance of high-temperature high-pressure drilling fluid | |
| CN113866069B (en) | Shale core permeability experimental device and method | |
| CN113310867B (en) | Experimental test method for simulating gas reservoir high-temperature high-pressure stratum reverse osmosis water absorption lock damage | |
| CN117433977B (en) | Supercritical CO 2 Device and method for detecting in-situ permeability of shale reaction | |
| CN111239023A (en) | System and method for testing rock compression coefficient under high-temperature and high-pressure conditions | |
| CN105422066A (en) | Method for reducing CO<2> flooding minimum miscible pressure | |
| CN112304842B (en) | Shale oil CO2/N2Alternating displacement injection quantity simulation analysis method | |
| CN105004650A (en) | Gas permeation testing method in low-permeability rock time-dependent deformation under action of thermal-gas-mecha-nical coupling | |
| CN111878075A (en) | Method for testing regional extraction degree of gas-water co-injection of inclined reservoir | |
| CN113777002B (en) | Shale oil seepage characteristic evaluation device and method | |
| CN205826624U (en) | A kind of long cores hydrocarbon gas drives experimental provision | |
| CN114352238A (en) | Device and method for testing flow conductivity of natural gas hydrate production increasing seam | |
| CN114439462A (en) | Research method for composition change of multiple injection-production fluid of condensate gas reservoir reconstruction gas storage |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |