CN109142160B - Method for characterizing unconventional petroleum associated mineral particle wettability based on suspension turbidity - Google Patents
Method for characterizing unconventional petroleum associated mineral particle wettability based on suspension turbidity Download PDFInfo
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- CN109142160B CN109142160B CN201811181126.8A CN201811181126A CN109142160B CN 109142160 B CN109142160 B CN 109142160B CN 201811181126 A CN201811181126 A CN 201811181126A CN 109142160 B CN109142160 B CN 109142160B
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- 239000002245 particle Substances 0.000 title claims abstract description 63
- 229910052500 inorganic mineral Inorganic materials 0.000 title claims abstract description 52
- 239000011707 mineral Substances 0.000 title claims abstract description 52
- 239000003208 petroleum Substances 0.000 title claims abstract description 26
- 238000000034 method Methods 0.000 title claims abstract description 23
- 239000000725 suspension Substances 0.000 title claims abstract description 23
- 238000012360 testing method Methods 0.000 claims description 19
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 claims description 12
- 239000011521 glass Substances 0.000 claims description 10
- YMWUJEATGCHHMB-UHFFFAOYSA-N Dichloromethane Chemical compound ClCCl YMWUJEATGCHHMB-UHFFFAOYSA-N 0.000 claims description 6
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 6
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Chemical compound O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 5
- 239000008367 deionised water Substances 0.000 claims description 4
- 229910021641 deionized water Inorganic materials 0.000 claims description 4
- 230000002209 hydrophobic effect Effects 0.000 claims description 4
- VLKZOEOYAKHREP-UHFFFAOYSA-N n-Hexane Chemical compound CCCCCC VLKZOEOYAKHREP-UHFFFAOYSA-N 0.000 claims description 4
- 239000003960 organic solvent Substances 0.000 claims description 4
- 238000009210 therapy by ultrasound Methods 0.000 claims description 3
- 238000001132 ultrasonic dispersion Methods 0.000 claims 1
- 239000003921 oil Substances 0.000 description 8
- 238000012512 characterization method Methods 0.000 description 5
- 239000007788 liquid Substances 0.000 description 4
- 238000000605 extraction Methods 0.000 description 3
- 239000002358 oil sand bitumen Substances 0.000 description 3
- 239000010426 asphalt Substances 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 238000005259 measurement Methods 0.000 description 2
- 239000003027 oil sand Substances 0.000 description 2
- 238000004062 sedimentation Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000018044 dehydration Effects 0.000 description 1
- 238000006297 dehydration reaction Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000010790 dilution Methods 0.000 description 1
- 239000012895 dilution Substances 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 238000000691 measurement method Methods 0.000 description 1
- 239000004058 oil shale Substances 0.000 description 1
- 239000003495 polar organic solvent Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 238000011144 upstream manufacturing Methods 0.000 description 1
- 239000002569 water oil cream Substances 0.000 description 1
- 238000009736 wetting Methods 0.000 description 1
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N13/00—Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N15/00—Investigating characteristics of particles; Investigating permeability, pore-volume or surface-area of porous materials
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- Life Sciences & Earth Sciences (AREA)
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- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
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- Pathology (AREA)
- Dispersion Chemistry (AREA)
- Sampling And Sample Adjustment (AREA)
Abstract
The invention discloses a method for representing the wettability of unconventional petroleum associated mineral particles based on suspension turbidity. The method is simple, convenient, feasible, economical and efficient, and has important significance for representing the wettability of the associated mineral particles of the unconventional petroleum resources.
Description
Technical Field
The invention belongs to the field of unconventional petroleum resources, and particularly relates to a method for characterizing the wettability of unconventional petroleum associated mineral particles based on suspension turbidity.
Background
With the decreasing of light petroleum resources, the status of unconventional petroleum resources, such as heavy oil, oil sand bitumen, oil shale, etc., in the world energy structure becomes more and more important. Unconventional petroleum is mostly stored in a mineral matrix, and the close combination of oil and mineral particles is a big feature of unconventional petroleum resources. The presence of these mineral particles presents a significant challenge to the cleanup of unconventional petroleum and is therefore critical to the understanding and characterization of unconventional petroleum associated mineral particles.
The wettability of the mineral particles determines the ease of oil-ore separation: the more lipophilic the mineral particles are, the more strongly binding to the oil phase and thus the more difficult it is to separate from the oil phase. Meanwhile, the incomplete organic adsorption on the surface of the mineral particles enables the mineral particles to have hydrophilic and oleophilic amphiphilic characteristics, the amphiphilic mineral particles are easy to stabilize oil-water emulsion, and the difficulty of dehydration and desanding is further aggravated. Therefore, the characterization work of the wettability of the unconventional oil associated mineral particles has important significance for guiding the exploitation and utilization of unconventional oil.
At present, the characterization methods aiming at the wettability of the mineral particles are few and the characterization effect is not ideal. Such as the commonly used contact angle measurement: the method for obtaining the mineral particle thin slice by tabletting and then measuring the contact angle of water drops on the thin slice has the defects of large measurement error, complex sample preparation process, large damage to the particle surface and the like. The invention aims to provide a simple and efficient method for characterizing the wettability of mineral particles. After the unconventional petroleum is subjected to upstream extraction, dilution, purification and other processes, the particle size of mineral particles mixed into the product oil is mostly smaller than 10 microns and the particle size distribution is similar, and the sedimentation behavior of the mineral particles in a liquid medium is mainly determined by the interaction force between the particles and the liquid. According to a similar compatibility principle, poorly wetting (hydrophobic) particles settle more slowly in non-polar organic solvents and thus the upper layer has a greater concentration of particles, macroscopically manifested as a greater turbidity of the suspension, and vice versa. Based on the method, the invention uses an indirect measurement method to quantitatively characterize the wettability of the mineral particles by analyzing the sedimentation behavior of the mineral particles in different liquid media and measuring the turbidity of suspension liquid and calculating the turbidity coefficient.
Disclosure of Invention
The invention aims to provide a method for characterizing the wettability of unconventional petroleum associated mineral particles, which can simplify the testing process and improve the testing precision.
The technical scheme for realizing the purpose of the invention is as follows:
a method for characterizing the wettability of unconventional petroleum associated mineral particles based on the turbidity of a suspension comprises the following steps:
(1) 0.3 g of mineral particles to be tested are placed in a glass bottle special for turbidity test, and then an organic solvent is added to the scribed line of the test bottle (30 mL). The suspension obtained is placed in an ultrasonic disperser to be subjected to ultrasonic treatment for 5 minutes and then taken out, is kept stand for 2 hours, is subjected to turbidity test, and records the turbidity obtained as TO；
(2) 0.3 g of mineral particles to be tested are placed in a glass bottle special for turbidity test, and then deionized water is added to the scribed line (30 mL) of the test bottle. The suspension obtained is placed in an ultrasonic disperser to be subjected to ultrasonic treatment for 5 minutes and then taken out, is kept stand for 2 hours, is subjected to turbidity test, and records the turbidity obtained as TW；
(3) Calculating a turbidity coefficient T for evaluating the wettability of the mineral particles, said turbidity coefficient being defined as T = TO/TWThe greater the turbidity coefficient, the poorer the wettability (the more hydrophobic) of the mineral particles.
The mineral particles have a particle size of less than 10 microns.
The organic solvent can be one or more of toluene, methanol, ethanol, dichloromethane or n-hexane.
The invention has the beneficial effects that: the wettability of suspended particles is indirectly characterized by testing the turbidity of the unconventional petroleum associated mineral particle suspension. The method is novel in concept, simple and feasible, and accurate and reliable in test result, and provides a quantitative characterization means for the wettability of unconventional petroleum associated minerals. The method can effectively study the wettability change characteristics of the conventional petroleum associated mineral particles, further optimize the solid particle removal process and guide the development and utilization practice of unconventional low-grade petroleum resources.
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FIG. 1 is a schematic diagram of a method for characterizing the wettability of unconventional petroleum associated mineral particles based on the turbidity of a suspension.
Detailed Description
The method can simply, conveniently and accurately represent the wettability of unconventional petroleum associated mineral particles, and is further explained by combining specific examples.
A method for characterizing the wettability of unconventional petroleum associated mineral particles based on the turbidity of a suspension comprises the steps of preparing a suspension of mineral particles, measuring the turbidity, and calculating the turbidity coefficient. The following are specific examples, but the present invention is not limited to the following examples.
Example 1
A method for characterizing the wettability of unconventional petroleum associated mineral particles based on the turbidity of a suspension comprises the following steps:
(1) 0.3 g of the mineral particles separated from the oil sand bitumen froth (average particle size 2.2 microns, contact angle 97 ℃) was placed in a turbidity test glass bottle and 30 mL of toluene was added. The resulting suspension was placed in an ultrasonic disperser and sonicated for 5 minutes, then taken out, allowed to stand for 2 hours, and then tested for turbidity. The average turbidity values for three replicates were: t isO=27.5 NTU。
(2) 0.3 g of mineral fines (average particle size 2.2 microns, contact angle 97 °) isolated from the oil sand bitumen froth was placed in a turbidity test dedicated glass bottle and 30 mL of deionized water was then added. The resulting suspension was placed in an ultrasonic disperser and sonicated for 5 minutes, then taken out, allowed to stand for 2 hours, and then tested for turbidity. Mean turbidity of triplicate determinationsThe values are: t isW=662 NTU。
(3) The turbidity coefficient T was calculated for evaluation of mineral particle wettability, resulting in a turbidity coefficient T = 0.042.
Example 2
A method for characterizing the wettability of unconventional petroleum associated mineral particles based on the turbidity of a suspension comprises the following steps:
(1) mineral particles (average particle diameter 1.8 μm, contact angle 139 °) separated from bitumen oil obtained by anhydrous extraction of oil sand, 0.3 g, were placed in a glass bottle dedicated to turbidity tests, and then 30 mL of toluene was added. The resulting suspension was placed in an ultrasonic disperser and sonicated for 5 minutes, then taken out, allowed to stand for 2 hours, and then tested for turbidity. The average turbidity values for three replicates were: t isO=42.5 NTU。
(2) Mineral particles (average particle diameter 1.8 microns, contact angle 139 °) separated from bitumen oil obtained by anhydrous extraction of oil sand, 0.3 g, were placed in a glass bottle dedicated to turbidity tests, and 30 mL of deionized water was then added. The resulting suspension was placed in an ultrasonic disperser and sonicated for 5 minutes, then taken out, allowed to stand for 2 hours, and then tested for turbidity. The average turbidity values for three replicates were: t isW=248 NTU。
(3) The turbidity coefficient T was calculated for evaluation of mineral particle wettability, and the resulting turbidity coefficient was T = 0.171.
Comparing the results of the above two examples, it can be seen that the turbidity coefficient (0.171) of the sample of example 2 is greater than that (0.042) of the sample of example 1, and therefore it can be concluded that the sample of example 2 is less wettable and more hydrophobic than the sample of example 1. This conclusion, which is consistent with the sample contact angle data, demonstrates the effectiveness of the method of the present invention.
Claims (2)
1. A method for characterizing the wettability of unconventional petroleum associated mineral particles based on the turbidity of a suspension, characterized by: the steps are as follows
(1) Taking 0.3 g of mineral particles to be tested, placing the mineral particles in a special glass bottle for turbidity test, adding an organic solvent to 30 mL of scribed lines in the special glass bottle for turbidity test, and placing the obtained suspension in an ultrasonic dispersion wayThe sample was sonicated for 5 minutes and then removed, allowed to stand for 2 hours, then turbidity was measured and the resulting turbidity was recorded as TO；
(2) Placing 0.3 g of mineral particles to be tested in a special glass bottle for turbidity test, adding deionized water to 30 mL of scribed lines in the special glass bottle for turbidity test, placing the obtained suspension in an ultrasonic disperser, performing ultrasonic treatment for 5 minutes, taking out, standing for 2 hours, performing turbidity test, and recording the obtained turbidity as TW；
(3) Calculating a turbidity coefficient T for evaluating the wettability of the mineral particles, said turbidity coefficient being defined as T = TO/TWThe larger the turbidity coefficient, the poorer and more hydrophobic the wettability of the mineral particles;
the mineral particles have a particle size of less than 10 microns.
2. The method for characterizing the wettability of unconventional petroleum associated mineral particles based on the turbidity of a suspension according to claim 1, wherein: the organic solvent in the step (1) can be one or more of toluene, methanol, ethanol, dichloromethane or n-hexane.
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