CN117761102A - Device and method for measuring evaporation degree of humidifying natural gas to formation water - Google Patents
Device and method for measuring evaporation degree of humidifying natural gas to formation water Download PDFInfo
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- CN117761102A CN117761102A CN202311748384.0A CN202311748384A CN117761102A CN 117761102 A CN117761102 A CN 117761102A CN 202311748384 A CN202311748384 A CN 202311748384A CN 117761102 A CN117761102 A CN 117761102A
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- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 124
- 239000003345 natural gas Substances 0.000 title claims abstract description 62
- 239000008398 formation water Substances 0.000 title claims abstract description 43
- 238000001704 evaporation Methods 0.000 title claims abstract description 28
- 230000008020 evaporation Effects 0.000 title claims abstract description 28
- 238000000034 method Methods 0.000 title claims abstract description 17
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 48
- 239000007789 gas Substances 0.000 claims abstract description 45
- 238000005481 NMR spectroscopy Methods 0.000 claims abstract description 21
- 238000001035 drying Methods 0.000 claims abstract description 6
- 238000000655 nuclear magnetic resonance spectrum Methods 0.000 claims abstract description 5
- 239000012530 fluid Substances 0.000 claims abstract description 3
- 239000011435 rock Substances 0.000 claims description 23
- 238000006073 displacement reaction Methods 0.000 claims description 11
- 229920006395 saturated elastomer Polymers 0.000 claims description 11
- 230000000694 effects Effects 0.000 claims description 7
- 239000002994 raw material Substances 0.000 claims description 6
- 238000012545 processing Methods 0.000 claims description 5
- 238000009826 distribution Methods 0.000 claims description 3
- 238000012360 testing method Methods 0.000 claims description 3
- 230000008676 import Effects 0.000 claims description 2
- 150000003839 salts Chemical class 0.000 abstract description 10
- 238000003860 storage Methods 0.000 abstract description 8
- 238000011161 development Methods 0.000 abstract description 3
- 238000011065 in-situ storage Methods 0.000 abstract 1
- 230000015572 biosynthetic process Effects 0.000 description 7
- 238000004519 manufacturing process Methods 0.000 description 5
- 230000008569 process Effects 0.000 description 4
- 239000007788 liquid Substances 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 238000012986 modification Methods 0.000 description 3
- 230000004048 modification Effects 0.000 description 3
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 230000001276 controlling effect Effects 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000001228 spectrum Methods 0.000 description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 239000002274 desiccant Substances 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 208000001491 myopia Diseases 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000002407 reforming Methods 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- QAOWNCQODCNURD-UHFFFAOYSA-N sulfuric acid Substances OS(O)(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-N 0.000 description 1
- 239000002912 waste gas Substances 0.000 description 1
Classifications
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- 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
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Abstract
The invention discloses a device and a method for measuring the evaporation degree of a humidifying natural gas to formation water, which belong to the technical field of gas reservoir gas storage development, and comprise a core holder for holding a core, a back pressure valve positioned on an outlet pipeline of the core holder, a flowmeter for measuring fluid after the back pressure valve, and a nuclear magnetic resonance spectrometer for measuring nuclear magnetic resonance spectrum of the core; a gas drying device positioned between the back pressure valve and the gas flowmeter; a first piston container storing formation water; a second piston container for storing natural gas and formation water; a high-pressure automatic pump for pushing the pistons in the first piston container and the second piston to move; the first piston container and the second piston container are connected in parallel and can be independently communicated with the core holder inlet. The invention provides a method for measuring the evaporation degree of natural gas to stratum water based on the nuclear magnetic resonance principle for the first time, and can well meet the requirement of diagnosing the damage degree of salt to the gas storage in situ.
Description
Technical Field
The invention relates to the technical field of development of gas reservoir type gas storage, in particular to a device and a method for measuring the evaporation degree of humidifying natural gas to formation water.
Background
Underground gas reservoirs are the most economical and effective means for ensuring season peak shaving and stable gas supply, however, reservoir salt formation is a common phenomenon in the development process of stratum water gas reservoirs with high mineralization. In the production process of gas storage wells, salt is often formed at the positions of stratum, oil sleeve, oil (gas) nozzle, gathering pipeline and the like due to the change of conditions such as pressure, temperature and the like and the thermodynamic instability of water. Salt formation in the gas storage seriously affects normal production. Part of the wells are abandoned too early due to salt formation near the production layer and the borehole of the well, for example, the salt content (NaCl) of stratum water of part of the wells in the Wen 96 gas storage is up to 30 ten thousand mg/L, so that salt formation occurs in the gas wells and near-wellbore zones, and normal production cannot be realized. In the process of multi-cycle operation of the gas storage, the continuous evaporation of formation water by dry natural gas is a root cause of salt formation of the reservoir, so that a device and a method for measuring the evaporation degree of the humidifying natural gas on the formation water are urgently needed for researching the influence of the humidifying natural gas on the water saturation of the reservoir.
Disclosure of Invention
In order to solve the above problems, an object of the present invention is to provide an apparatus and a method for measuring the influence of humidifying natural gas on water saturation of a reservoir, which can measure the evaporation degree of the humidifying natural gas on formation water.
In order to achieve the above object, the present invention is as follows:
an apparatus for measuring the extent of evaporation of formation water by a humidified natural gas, comprising: the utility model provides a rock core holder for centre gripping rock core, is located the back pressure valve on rock core holder outlet pipeline for fluid meter behind the back pressure valve measures, and rock core holder import and export are equipped with the manometer, its characterized in that still includes:
a nuclear magnetic resonance spectrometer for determining a nuclear magnetic resonance spectrum of the core;
a gas drying device positioned between the back pressure valve and the gas flowmeter;
a first piston container storing formation water;
a second piston container for storing natural gas and formation water;
a high-pressure automatic pump for pushing the pistons in the first piston container and the second piston to move;
the first piston container and the second piston container are connected in parallel and can be independently communicated with the core holder inlet.
In one embodiment of the present invention, the apparatus further comprises an exhaust gas treatment device for treating the gas metered by the flowmeter.
As a specific embodiment of the invention, the system further comprises a data processing system for collecting and storing data of the nuclear magnetic resonance apparatus, the pressure gauge and the flow meter.
As a specific embodiment of the present invention, the core holder is a high temperature and high pressure nuclear magnetic resonance core holder, and reference may be made to patent CN201910457379.1, in which the second piston container is located in a first incubator, the second piston container to the core holder inlet line is located in a second incubator, the first piston container to the core holder inlet line is located in the second incubator, and the temperature in the first incubator is not higher than the temperature in the second incubator.
A device for measuring the degree of evaporation of formation water by humidified natural gas, comprising the steps of:
s1, adopting stratum water saturated rock core;
s2, testing T of rock core of saturated stratum water 2 A map;
s3, using the humidified natural gas to displace the core, and measuring nuclear magnetic resonance T of the core 2 A map;
s4, calculating an evaporation index I of formation water in the rock core; the evaporation index is calculated as follows:
wherein I is the evaporation index of stratum water in the rock core, and is dimensionless;P i1 the signal amplitude of the core which is saturated with formation water in the relaxation time period i is dimensionless; p (P) i2 Signal amplitude of the core for humidifying natural gas displacement in a relaxation time period i is dimensionless; t (T) 2i Representative sample Nuclear magnetic resonance T 2 The length of the ith relaxation time period in the distribution is dimensionless; r is the radius of the core, cm; h is the length of the core, cm; θ is core porosity, dimensionless; omega is the volume content of water in the gas phase of the core, and is dimensionless.
As a specific embodiment of the present invention, the method further comprises the step of determining the water content in the humidified natural gas, specifically: filling water into a second container, measuring the effective volume V1 of the raw materials contained in the second container, adding formation water into the second container, wherein the addition amount of the formation water is lower than the effective volume V1 of the raw materials contained in the second container, measuring the volume V2 of the formation water in the second container at the moment, adding dry natural gas into the second container, and reforming gas-liquid balance after the natural gas enters, namely, part of the formation water volatilizes into the natural gas, measuring the volume V3 of the formation water in the second container after the dry natural gas is added, wherein the volume water content of the natural gas in the second container at the moment is as follows:
compared with the prior art, the invention has the following technical effects:
the invention provides a device and a method for measuring the evaporation degree of natural gas on formation water, which firstly provides a method for measuring the evaporation degree of natural gas on formation water based on a nuclear magnetic resonance principle, and judges the influence degree of gas flooding on the water saturation of a rock core through the change of the peak area of a rock core nuclear magnetic resonance T2 map; meanwhile, the method for measuring the nuclear magnetic resonance spectrum of the core on line simulates the real stratum condition, overcomes the defect that the conventional nuclear magnetic resonance T2 spectrum measurement needs to take out the core for measurement, and can better simulate the production condition of the real stratum on line. According to the difference of core nuclear magnetic resonance T2 maps obtained by different displacement gases (dry gas, moisture added and the like), the intensity of the core evaporation effect of the different displacement gases is judged, a basis is provided for the next step of taking corresponding measures for treating reservoir salt formation in the gas storage, and the requirement for diagnosing the damage degree of the reservoir salt formation on site can be well met through the nuclear magnetic resonance T2 maps of online nuclear magnetic measurement, and the obtained result is more reasonable and reliable. The method can be used for measuring the influence of the humidifying natural gas on the stratum water evaporation degree, can be popularized and used for measuring the influence of CO2 in the CO2 burying process on the stratum water evaporation degree of the reservoir, and has a wide application value.
Drawings
FIG. 1 is a schematic diagram of an apparatus for measuring the effect of humidified natural gas on the water saturation of a reservoir according to example 1 of the present invention;
figure 2 is the evaporation index for the dry natural gas and wet natural gas displacement of example 1.
Detailed Description
The present invention will be described in further detail with reference to examples and drawings, but embodiments of the present invention are not limited thereto.
Example 1
Referring to fig. 1, there is shown a specific structure of an apparatus for measuring the evaporation degree of a humidifying natural gas to formation water according to the present invention, which includes a high-pressure automatic pump 1, three-way valves, namely, a first three-way valve 21, a second three-way valve 22, a third three-way valve 23 and a fourth three-way valve 24, respectively, a first piston container 3 containing formation water, a second piston container 4 containing natural gas and formation water, two valves, namely, a first valve 51 and a second valve 52, a pressure reducing valve 6, three pressure gauges, namely, a first pressure gauge 71, a second pressure gauge 72 and a third pressure gauge 73, a core holder 8, a nuclear magnetic resonance apparatus 9, a back pressure valve 10, a manual pump 11, a gas drying apparatus 12, a high-precision flow meter 13, a data processing system 14 and an exhaust gas processing apparatus 15.
The high-pressure automatic pump 1 is communicated with the first piston container 4 and the second piston container 5 through the first three-way valve 21, and the outlets of the first piston container 4 and the second piston container 5 are respectively communicated with the second three-way valve 21, so that the pistons in the first piston container 4 and the second piston container 5 can be independently driven to move by the high-pressure automatic pump 1, thereby realizing displacement; the outlet of the second three-way valve 22 is sequentially connected with a first valve 51, a pressure reducing valve 6, a third three-way valve 23, a core holder 8 and a back pressure valve 9, the gas drying device 12, the high-precision flowmeter 13 and the waste gas treatment device 15, the first pressure gauge 71 and the second pressure gauge 72 are arranged at the inlet and outlet of the core holder 8 and used for measuring the pressure difference during displacement, and the nuclear magnetic resonance instrument 9 is used for scanning the core in the core holder 8 and obtaining a T2 map thereof; the manual pump 11 is used for controlling the back pressure valve, thereby controlling the back pressure of the displacement; the gas drying device 12 is used for removing moisture in the gas, the drying agent such as concentrated sulfuric acid, calcium carbonate and the like is filled in the device, the exhaust gas treatment device 15 can be an alcohol lamp for burning the gas, or the exhaust gas can be led into an exhaust pipeline of a laboratory for centralized treatment, and the data processing system 14 is used for recording data in the experimental process, including gas flow.
When in experiment, the device is connected and the air tightness of the device is checked, the vacuum pump can be used for vacuumizing the interior of the device, and whether the air tightness is qualified or not is determined according to the descending amount of the vacuum degree; air tightness was acceptable and the following operations were performed:
s1, adopting stratum water saturated rock core: taking a target horizon standard core (with the diameter of 2.5cm and the length of 3-5 cm), pressurizing a first piston container filled with stratum water by using a high-pressure gas pump, and using stratum water to displace the core for 5min at the speed of 5mL/min, wherein basic parameters of the core are as follows;
table 1 core base parameters
| Sequence number | Dry weight (g) | Length (mm) | Diameter (mm) | Porosity (%) | Permeability (mD) |
| 1 | 53.1102 | 50.94 | 24.50 | 16.21 | 8.496 |
S2, testing T of rock core of saturated stratum water 2 The nuclear magnetic resonance spectrum at the moment is a T2 spectrum when the rock core is completely saturated with stratum water;
s3, using the humidified natural gas to displace the core, and measuring nuclear magnetic resonance T of the core 2 A map; using natural gas (gas in a second container) to displace the core, and measuring a T2 map of the core every 5 minutes;
s4, calculating an evaporation index I of formation water in the rock core; the evaporation index is calculated as follows:
wherein I is the evaporation index of stratum water in the rock core, and is dimensionless; p (P) i1 The signal amplitude of the core which is saturated with formation water in the relaxation time period i is dimensionless; p (P) i2 Signal amplitude of the core for humidifying natural gas displacement in a relaxation time period i is dimensionless; t (T) 2i Representing the length of the ith relaxation time period in the nuclear magnetic resonance T2 distribution of the sample, and having no dimension; r is the radius of the core, cm; h is the length of the core, cm; θ is core porosity, dimensionless; omega is the volume content of water in the gas phase of the core, and is dimensionless.
The present example measured dry natural gas (no formation water is added to the second vessel) and humidified natural gas (formation water is added to the second vessel) as displacement gases, respectively, and the evaporation intensity at each time was calculated, and the specific results are shown in fig. 2.
In addition, the second vessel contains moisture content of the humidified natural gas (moisture which can be shortsighted as a gas phase in the coreThe amount) may be obtained by filling the second container with water, measuring the effective volume V1 of the material contained in the second container, adding formation water to the second container in an amount lower than the effective volume V1 of the material contained in the second container, measuring the volume V2 of the formation water in the second container at this time, then adding dry natural gas to the second container, after which the natural gas will reform into a gas-liquid equilibrium, i.e. part of the formation water will volatilize into the natural gas, measuring the volume V3 of the formation water in the second container after adding dry natural gas, then the volume water content of the natural gas in the second container at this time is:
example 2
The device for measuring the evaporation degree of the humidifying natural gas to the formation water in the embodiment is further improved on the basis of the device in the embodiment 1, and the specific improvement points are as follows:
1. the core holder in this embodiment is a high-temperature high-pressure nuclear magnetic resonance core holder, and reference may be made to patent CN201910457379.1.
2. In this embodiment, two thermostats, namely, a first incubator and a second incubator are added, wherein the second piston container is located in the first incubator, the inlet pipeline from the second piston container to the core holder is located in the second incubator, the inlet pipeline from the second piston container to the core holder is also located in the second incubator, and the temperature in the first incubator is not higher than the temperature in the second incubator. Thus, the water saturation of the generated natural gas can be adjusted by adjusting the temperature in the first constant temperature box, and the water content of the natural gas can be improved by increasing the temperature in the first constant temperature box.
During experimental operation, water is filled into a second container, the effective volume V1 of the raw materials in the second container is measured, stratum water is added into the second container, the addition amount of the stratum water is lower than the effective volume V1 of the raw materials in the second container, the second container is heated to the target temperature T1 through a first constant temperature box, the volume V2 of the stratum water in the second container is measured after 1h, then dry natural gas is added into the second container, and the natural gas entersAnd then the gas-liquid balance is formed again, namely part of stratum water volatilizes into natural gas, after 1h, the volume V3 of stratum water in the second container is measured after the dry natural gas is added, and then the volume water content of the natural gas in the second container is as follows:
in addition, when saturated water and humidifying natural gas are adopted for displacement, the temperature of the core holder is adjusted to be the stratum temperature T 2 Regulating the temperature level T of the second constant temperature box 2 And T is 2 >T 1 Therefore, the experiment can be carried out by adopting the gases with different water contents, and the real temperature and pressure conditions of the stratum can be simulated.
The present invention is not limited to the above-mentioned embodiments, but is not limited to the above-mentioned embodiments, and any person skilled in the art can make some changes or modifications to the equivalent embodiments without departing from the scope of the technical solution of the present invention, but any simple modification, equivalent changes and modifications to the above-mentioned embodiments according to the technical substance of the present invention are still within the scope of the technical solution of the present invention.
Claims (6)
1. An apparatus for measuring the extent of evaporation of formation water by a humidified natural gas, comprising: the utility model provides a rock core holder for centre gripping rock core, is located the back pressure valve on rock core holder outlet pipeline for fluid meter behind the back pressure valve measures, and rock core holder import and export are equipped with the manometer, its characterized in that still includes:
a nuclear magnetic resonance spectrometer for determining a nuclear magnetic resonance spectrum of the core;
a gas drying device positioned between the back pressure valve and the gas flowmeter;
a first piston container storing formation water;
a second piston container for storing natural gas and formation water;
a high-pressure automatic pump for pushing the pistons in the first piston container and the second piston to move;
the first piston container and the second piston container are connected in parallel and can be independently communicated with the core holder inlet.
2. The apparatus for measuring the effect of humidified natural gas on the water saturation of a reservoir according to claim 1, further comprising means for treating the gas as measured by the flow meter.
3. The apparatus for measuring the effect of humidified natural gas on the water saturation of a reservoir according to claim 1, further comprising a data processing system for collecting and storing data from the nmr apparatus, the manometer, the flowmeter.
4. The apparatus of claim 1, wherein the core holder is a high temperature high pressure nuclear magnetic resonance core holder, the second piston vessel is located in a first incubator, the second piston vessel to core holder inlet line is located in a second incubator, the first piston vessel to core holder inlet line is located in a second incubator, and the temperature in the first incubator is no higher than the temperature in the second incubator.
5. A method of measuring the effect of humidified natural gas on the water saturation of a reservoir comprising the steps of:
s1, adopting stratum water saturated rock core;
s2, testing T of rock core of saturated stratum water 2 A map;
s3, using the humidified natural gas to displace the core, and measuring nuclear magnetic resonance T of the core 2 A map;
s4, calculating an evaporation index I of formation water in the rock core:
wherein I is the evaporation index of stratum water in the rock core, and is dimensionless; p (P) i1 The signal amplitude of the core which is saturated with formation water in the relaxation time period i is dimensionless; p (P) i2 Signal amplitude of the core for humidifying natural gas displacement in a relaxation time period i is dimensionless; t (T) 2i Representative sample Nuclear magnetic resonance T 2 The length of the ith relaxation time period in the distribution is dimensionless; r is the radius of the core, cm; h is the length of the core, cm; θ is core porosity, dimensionless; omega is the volume content of water in the gas phase of the core, and is dimensionless.
6. An apparatus for measuring the effect of humidified natural gas on the water saturation of a reservoir as claimed in claim 5, wherein the step of determining the water content of the humidified natural gas in the second piston vessel:
filling the second container with water, and measuring the effective volume v1 of the raw material contained in the second container;
adding formation water into the second container, wherein the addition amount of the formation water is lower than the effective volume V1 of the raw materials contained in the second container, and measuring the volume V2 of the formation water in the second container at the moment;
then adding dry natural gas into the second container, and measuring the volume V3 of formation water in the second container after the dry natural gas is added;
wherein the volume water content of the natural gas in the second container is:
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Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106154343A (en) * | 2015-04-24 | 2016-11-23 | 中国石油天然气股份有限公司 | Method for calculating oil saturation of tight oil reservoir |
| CN111537541A (en) * | 2020-05-26 | 2020-08-14 | 西安石油大学 | Compact reservoir CO2Method for evaluating driving characteristics of reservoir |
| US11099292B1 (en) * | 2019-04-10 | 2021-08-24 | Vinegar Technologies LLC | Method for determining the composition of natural gas liquids, mean pore-size and tortuosity in a subsurface formation using NMR |
-
2023
- 2023-12-19 CN CN202311748384.0A patent/CN117761102A/en active Pending
Patent Citations (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106154343A (en) * | 2015-04-24 | 2016-11-23 | 中国石油天然气股份有限公司 | Method for calculating oil saturation of tight oil reservoir |
| US11099292B1 (en) * | 2019-04-10 | 2021-08-24 | Vinegar Technologies LLC | Method for determining the composition of natural gas liquids, mean pore-size and tortuosity in a subsurface formation using NMR |
| CN111537541A (en) * | 2020-05-26 | 2020-08-14 | 西安石油大学 | Compact reservoir CO2Method for evaluating driving characteristics of reservoir |
Non-Patent Citations (2)
| Title |
|---|
| 任星明: "东方13-1高温高压气藏凝析水析出规律及积液风险研究", 中国优秀硕士学位论文全文数据库（工程科技I辑）, no. 11, 15 November 2017 (2017-11-15), pages 1 - 68 * |
| 郭新成 等: "基于核磁共振技术表征致密油藏 CO2混合气体驱替原油动用特征实验研究", 2023油气勘探与开发国际会议论文集III, 30 November 2023 (2023-11-30), pages 657 - 669 * |
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