CN115895635A - Fracturing fluid oil displacement agent and fracturing fluid - Google Patents
Fracturing fluid oil displacement agent and fracturing fluid Download PDFInfo
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Abstract
The invention provides a fracturing fluid oil displacement agent and a fracturing fluid, wherein the fracturing fluid oil displacement agent comprises the following raw materials in parts by weight: 6-10 parts of fatty alcohol-polyoxyethylene ether, 3-5 parts of anionic surfactant, 0.5-1 part of pH regulator and 30-50 parts of deionized water. The fracturing fluid imbibition agent disclosed by the invention is compounded by adopting a nonionic surfactant fatty alcohol-polyoxyethylene ether and an anionic surfactant, so that the salt resistance and the high temperature resistance of the fracturing fluid can be effectively improved, and the fracturing fluid imbibition agent still has good stability and fluidity at the temperature of more than 80 ℃.
Description
Technical Field
The invention relates to the field of oil exploitation, in particular to a fracturing fluid oil displacement agent, and also relates to a fracturing fluid comprising the fracturing fluid oil displacement agent.
Background
The exploitation of oil field is divided into primary oil recovery, secondary oil recovery and tertiary oil recovery. The primary oil recovery and the secondary oil recovery of the oil field can only recover about 1/3 of the total crude oil, and the residual 2/3 of the crude oil needs to be recovered for the third time. In the third oil recovery, the oil yield needs to be improved by adding a surfactant and the like. In the exploitation process, a fracturing technology is usually adopted, and the fracturing aims to mainly form a high-conductivity fracture with a certain geometric shape, improve a fluid passage path and greatly improve the yield of oil and gas.
The fracturing fluid in the fracturing technology is a heterogeneous unstable chemical system formed by a plurality of additives according to a certain proportion, is a working fluid used for fracturing and reforming an oil-gas layer, and mainly has the functions of transmitting high pressure formed by ground equipment into a stratum, enabling the stratum to fracture to form cracks and conveying a propping agent along the cracks. The imbibition agent in the fracturing fluid is usually a surfactant, and can reduce the oil-water interfacial activity and the surface activity, improve the capillary self-absorption effect, synergistically displace the crude oil into a high-permeability crack, and further carry the crude oil out during water flooding. However, the existing imbibition agent for fracturing has poor salt resistance, is easy to hydrolyze and lose efficacy, and has large stratum adsorption loss. Therefore, the invention of the fracturing fluid imbibition agent with better salt resistance, high temperature resistance and formation adsorption resistance has great significance for improving the recovery ratio of tight oil reservoirs.
Disclosure of Invention
In view of the above, the invention provides a fracturing fluid imbibition agent to improve the high temperature resistance of a fracturing fluid.
The fracturing fluid oil displacement agent comprises the following raw materials in parts by weight: 6-10 parts of fatty alcohol-polyoxyethylene ether, 3-5 parts of anionic surfactant, 0.5-1 part of pH regulator and 30-50 parts of deionized water.
Further, the type of the fatty alcohol-polyoxyethylene ether is AEO-7.
Further, the anionic surfactant is dodecyl benzene sulfonate.
Further, the anionic surfactant is sodium dodecyl benzene sulfonate.
Further, the pH regulator is a metal hydroxide.
Further, the pH regulator is sodium hydroxide.
Further, the fracturing fluid oil displacement agent comprises the following raw materials in parts by weight: 8 parts of fatty alcohol-polyoxyethylene ether, 4 parts of anionic surfactant, 0.8 part of pH regulator and 40 parts of deionized water.
According to the invention, the nonionic surfactant fatty alcohol-polyoxyethylene ether and the anionic surfactant are compounded to form a microemulsion type, so that the salt resistance and the high temperature resistance of the fracturing fluid can be effectively improved, and the fracturing fluid still has good stability and fluidity at the temperature of more than 80 ℃.
The invention also provides a fracturing fluid, and the preparation raw material of the fracturing fluid comprises the fracturing fluid oil displacement agent.
Detailed Description
It should be noted that the embodiments and features of the embodiments may be combined with each other without conflict.
The experimental procedures in the following examples are conventional unless otherwise specified. The test materials used in the following examples were purchased from a conventional biochemical reagent store unless otherwise specified. In addition, unless otherwise specified, all terms and processes related to the present embodiment should be understood according to the conventional knowledge and conventional methods in the art.
The method for measuring the product performance comprises the following steps:
1 capillary self-priming height
1.1 preparation of oleophilic capillaries
1.1.1 capillary specs: the inner diameter of the standard capillary is 0.35mm, and carbon tetrachloride and benzene are sequentially used for the following steps: acetone: ethanol =7 (volume ratio);
1.1.2, sequentially performing ultrasonic treatment on the surface of the capillary tube by using a dilute hydrochloric acid solution (1; ultrasonic cleaning with deionized water to remove residual acid until pH is greater than 6.5, and oven drying at 105 deg.C;
1.1.3 preparing aging oil according to the proportion, wherein the aging oil comprises crude oil: aviation kerosene: 90# asphalt = 2; completely immersing the treated capillary tube in aging oil, and aging for 30 days at the temperature of 60 ℃;
1.1.4 taking out the capillary, soaking the capillary for 2min by using kerosene to clean asphalt deposited on the inner wall and the outer wall of the capillary, wherein the observation is not influenced; and (3) blowing kerosene outside the tube by using nitrogen, placing the tube in a closed environment at 60 ℃ for drying to obtain an oil-wet capillary tube, and storing the tube for later use.
1.2 test sample preparation
1.2.1 preparing 0.03% solution to be detected by deionized water, adding a drop of blue ink, keeping the temperature of the solution at 25 +/-0.2 ℃, pouring the solution to be detected into a cuvette to the top end boundary, and tightly attaching a ruler to the rear wall and standing behind the ruler;
1.2.2 vertically placing the processed three capillaries in a cuvette, keeping the inclination angles of all the capillaries for testing consistent by using a glass slide, reading the height difference between the liquid level in the recording tube and the boundary at the top end of the cuvette, respectively recording the liquid level height of the capillaries when the capillaries are immersed in the liquid level for 10min, and taking the arithmetic mean value as the measurement result.
2 surface tension
Preparing 0.03 percent of fracturing fluid oil displacing agent solution by using deionized water, measuring the surface tension value of the prepared fracturing fluid oil displacing agent solution by using a surface tension meter at 25 ℃, continuously measuring for three times, and taking the average value of the values.
3 interfacial tension
Preparing a 0.03% fracturing fluid oil displacement agent solution by using deionized water, taking the prepared fracturing fluid oil displacement agent solution, measuring an interfacial tension value of the solution by using kerosene as a low-density phase at the temperature of 150 ℃ according to a rotating drop method specified by SY/T5370-1999 3.3, continuously measuring the interfacial tension value for three times, and taking an average value of the interfacial tension values.
4 temperature resistance
Preparing 200g of 0.03% fracturing fluid oil displacement agent solution by using deionized water, sealing, placing in a (150 +/-1) DEG C oven for aging for 15d, taking out a sample, respectively measuring according to methods 1, 2 and 3, and recording values of self-priming height, surface tension and interfacial tension after high-temperature aging, wherein the self-priming height is the liquid level height when the capillary tube is submerged in the liquid level for 10 min.
5 salt tolerance
5.1 simulated Water for experiments
Simulated water for fracturing fluid oil displacement agent experiments: placing a 5L narrow-necked flask on a 10kg balance, adding 4901.03g of deionized water to the narrow-necked flask, placing a magnetic stirrer, placing the magnetic stirrer on the magnetic stirrer, starting the stirrer to form a vortex of the solution, and adding the following substances in sequence: 5.7155g of anhydrous calcium chloride, 4.3201g of magnesium chloride hexahydrate and 88.9340g of sodium chloride. Each reagent is added until it is completely dissolved before the other reagent is added. Stirring with magnetic stirrer for 15 min. The total mineralization of the obtained solution is 19334mg/L, wherein the total amount of calcium ions and magnesium ions is 514mg/L. The prepared brine is required to be homogeneous and transparent, has no precipitation phenomenon and has the effective period of 7d.
5.2 simulation of capillary self-suction height
Preparing 0.3% fracturing fluid oil displacement agent solution by using simulated water in 5.1, measuring according to a method of 1.2, and recording a self-absorption height value.
6 spontaneous imbibition efficiency
6.1 saturated core
The process of directly saturating crude oil is used herein, without considering the effects of bound water for the moment. And (3) putting the beaker filled with the rock core into a vacuum drier, and respectively connecting the upper part of the beaker with a funnel and a vacuum pump through rubber plugs.
The core saturation step is as follows:
6.1.1 measuring the length and diameter of the core.
6.1.2 drying the core: 94 ℃ for 24 hours.
6.1.3 measurement record of core quality after drying
6.1.4 put the core into a vacuum dryer. An oil pipe is connected above the container, the oil pipe is connected with a separating funnel, and a funnel piston is closed.
6.1.5 core was evacuated for 3 hours.
6.1.6 the vacuum pump was turned off and the crude oil was poured into the funnel.
6.1.7 slowly open the funnel piston, let oil enter and completely cover the core. The funnel piston is closed.
6.1.8 cores were immersed in crude oil for 24h.
6.1.9 releasing the vacuum, taking out the cores one by one, sucking crude oil on the surface of the rock by paper, weighing the mass of the cores, and calculating the mass of the crude oil entering the cores.
6.1.10 the treated cores were placed in imbibition bottles and imbibition fluid was poured in.
6.1.11 record the volume of oil that is extracted from the core at intervals.
6.2 dialysis device
The saturated core is soaked in an imbibition bottle filled with imbibition liquid (the mineralization is 19334Mg/L, the sum of Ca2+ and Mg2+ is 514 Mg/L), and the caps at two ends are screwed down to prevent the liquid from volatilizing. Standing at the experimental temperature, and recording the volume of the precipitated oil drops along with the change of the volume of the precipitated oil drops along with the time.
Example 1
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment include 8g of AEO-7 type fatty alcohol polyoxyethylene ether, 4g of sodium dodecyl benzene sulfonate, 0.8g of sodium hydroxide and 40g of deionized water.
The fracturing fluid oil displacement agent obtained in this example was subjected to surface tension, interfacial tension and capillary self-suction height measurement according to the above-mentioned product performance measurement method, and the results are shown in table 1 below:
TABLE 1
Example 2
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment comprise 6g of AEO-7 type fatty alcohol polyoxyethylene ether, 5g of sodium dodecyl benzene sulfonate, 0.5g of sodium hydroxide and 30g of deionized water.
The fracturing fluid oil displacement agent obtained in this example was subjected to surface tension, interfacial tension and capillary self-suction height measurement according to the above-mentioned product performance measurement method, and the results are shown in table 2 below:
TABLE 2
Example 3
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment include 10g of AEO-7 type fatty alcohol polyoxyethylene ether, 3g of sodium dodecyl benzene sulfonate, 1g of sodium hydroxide and 50g of deionized water.
The fracturing fluid oil displacement agent obtained in the embodiment is subjected to surface tension, interfacial tension and capillary self-absorption height measurement according to the above product performance measurement method, and the results are shown in the following table 3:
TABLE 3
Example 4
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment are basically the same as those of the embodiment 1, except that the fatty alcohol-polyoxyethylene ether adopts AEO-3.
The fracturing fluid oil displacement agent obtained in the embodiment is subjected to surface tension, interfacial tension and capillary self-absorption height measurement according to the above product performance measurement method, and the results are shown in the following table 4:
TABLE 4
Example 5
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment are basically the same as that of the embodiment 1, except that the fatty alcohol-polyoxyethylene ether type is AEO-9.
The fracturing fluid oil displacement agent obtained in the embodiment is subjected to surface tension, interfacial tension and capillary self-absorption height measurement according to the above product performance measurement method, and the results are shown in the following table 5:
TABLE 5
Example 6
The fracturing fluid oil displacement agent of this example was prepared from substantially the same raw materials as in example 1, except that the anionic surfactant was a fatty alcohol sulfate ester salt.
The fracturing fluid oil displacement agent obtained in the embodiment is subjected to surface tension, interfacial tension and capillary self-absorption height measurement according to the above product performance measurement method, and the results are shown in the following table 6:
TABLE 6
Comparative example 1
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment include 5g of AEO-7 type fatty alcohol polyoxyethylene ether, 4g of sodium dodecyl benzene sulfonate, 0.8g of sodium hydroxide and 40g of deionized water.
The fracturing fluid oil displacement agent obtained in the embodiment is subjected to surface tension, interfacial tension and capillary self-absorption height measurement according to the above product performance measurement method, and the results are shown in the following table 7:
TABLE 7
Comparative example 2
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment include 11g of AEO-7 type fatty alcohol polyoxyethylene ether, 4g of sodium dodecyl benzene sulfonate, 0.8g of sodium hydroxide and 40g of deionized water.
The fracturing fluid oil displacement agent obtained in the embodiment is subjected to surface tension, interfacial tension and capillary self-absorption height measurement according to the above product performance measurement method, and the results are shown in the following table 8:
TABLE 8
Comparative example 3
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment include 8g of AEO-7 type fatty alcohol polyoxyethylene ether, 2.9g of sodium dodecyl benzene sulfonate, 0.8g of sodium hydroxide and 40g of deionized water.
The fracturing fluid oil displacement agent obtained in the embodiment is subjected to surface tension, interfacial tension and capillary self-absorption height measurement according to the above product performance measurement method, and the results are shown in the following table 9:
TABLE 9
Comparative example 4
The preparation raw materials of the fracturing fluid oil displacement agent of the embodiment include 8g of AEO-7 type fatty alcohol polyoxyethylene ether, 5.1g of sodium dodecyl benzene sulfonate, 0.8g of sodium hydroxide and 40g of deionized water.
The fracturing fluid oil displacement agent obtained in this example was subjected to surface tension, interfacial tension and capillary self-suction height measurement according to the above-mentioned product performance measurement method, and the results are shown in table 10 below:
watch 10
In the test data of the above examples, it is demonstrated that the fracturing fluid oil displacement agent prepared in example 1 has the best performance, and the proportion of each raw material has the best dosage.
AEO-7 type fatty alcohol-polyoxyethylene ether, fracturing fluid oil-displacing agent, were compared in example 1 with example 4 and example 5
Compared with the embodiment 6, the interfacial tension of the sodium dodecyl benzene sulfonate and the oil displacement agent of the fracturing fluid added with the sodium dodecyl benzene sulfonate is 0.39, which meets the test standard.
Compared with the comparative example 1, when the dosage of the fatty alcohol-polyoxyethylene ether is less than 6 parts, the fracturing fluid oil displacement agent is used.
Compared with the comparative example 2, when the dosage of the fatty alcohol-polyoxyethylene ether is more than 10 parts, the fracturing fluid oil displacement agent is prepared.
When the amount of the anionic surfactant is less than 3 parts, the most significant parameter effect of the fracturing fluid oil displacement agent is the magnitude of interfacial tension and shear intolerance, compared with example 1 and comparative example 3.
When the amount of the anionic surfactant is more than 5 parts, the interfacial tension of the fracturing fluid oil displacement agent is lower and the fracturing fluid oil displacement agent is not shear-resistant, compared with the case of example 1 and the case of comparative example 4.
Experimental conditions and methods:
(1) Materials and instruments:
the core used in the experiment is an artificial core, the size of the artificial core is 2.5cm multiplied by 10.0cm, and the permeability Ka is less than or equal to 1.0mD. The core saturated oil and dynamic flooding process adopts related methods and experimental steps in an industry standard SY/T6424-2000 (a composite flooding system performance test method). The oil sand experiment adopts quartz sand with sand grain number of 100-160 meshes and above 160 meshes or simulated oil sand added with clay components to prepare the oil sand oil according to the mass ratio of 7.
The imbibition mode of water agent alternate injection is to utilize a conventional physical simulation experiment device, and a certain amount of imbibition agent (0.1-0.3 PV) and a certain amount of water are injected into a rock core and then are subjected to heat preservation for a certain time to be used as a period, so that 1-3 periods are carried out. Static imbibition refers to a process of putting a rock core or oil sand into a self-absorption instrument, carrying out heat preservation observation under normal pressure, measuring the amount of separated oil, and then calculating the imbibition efficiency.
a. The main agent is nonionic surfactant, is fatty alcohol polyoxyethylene ether type, the following examples adopt fatty alcohol polyoxyethylene ether JFC-E, the hydrophilic-lipophilic balance value (HLB value) of the surfactant is 11.0-12.0, the pH value is 6.5-7.5 (0.01-0.2% aqueous solution), and the molecular weight is lower than 5000; the active matter content of the active agent is more than 90%, the active agent is easy to dissolve in water, has good wettability, permeability and emulsifying property, and is produced by Jiangsu Haian petrochemical plants.
b. The promoter is anionic active agent, including alkylbenzene sulfonate or sulfate, petroleum sulfonate, etc. The alkylbenzene sulfonate is sodium dodecyl benzene sulfonate to sodium octadecyl benzene sulfonate, which are all produced by Donghao fine chemical Co., ltd, wujiang, in the following examples, and the alkylbenzene sulfonate has an active matter content of more than 80% and is biodegradable. The petroleum sulfonate can also be produced by selecting target block crude oil as a raw material, or can be produced by Daqing refining company, and the active matter content is more than 40%. The above two types of anionic active agents are used herein primarily for functions of enhancing detergency and conditioning activity.
c. The water quality stabilizer has the functions of scale inhibition, stabilization and dispersion. In the examples, a TH607B barium strontium scale inhibitor (the barium strontium scale inhibition rate is more than 80% according to SY/T5673-1993 test) is selected, the pH is =6.0-7.0 (1.0% aqueous solution), the density is 1.10g/cm < 3 > at 20 ℃, the solid content is more than 40%, and the manufacturer is Shandongtai and water treatment science and technology Co., ltd. Other reagents were all commercially available.
(2) And (3) infiltration experiment:
a. static imbibition method: the method comprises the steps of putting a weighed rock core made of oil sand or saturated oil into the self-priming instrument, injecting a prepared imbibition agent aqueous solution with a certain content to a certain scale position of a graduated tube on the upper portion of the self-priming instrument, sealing the upper opening of the self-priming instrument, putting the self-priming instrument into a thermostat with adjusted temperature, preserving the temperature, recording the separated oil quantity at regular time, and calculating the imbibition efficiency.
b. Pressure fluctuation imbibition method: the pressure fluctuation imbibition experiment is carried out in the imbibition instrument provided by the invention patent, and the instrument is visual, pressure-resistant and temperature-resistant. Putting the saturated oil and aged rock core on a support of a lithology chamber of the imbibition instrument, injecting an imbibition agent and exhausting air, putting the imbibition instrument in a constant temperature box at 80 ℃, connecting a pipeline, detecting the tightness, switching on the operation of annular pressure, adjusting the annular pressure, exhausting air and the like, keeping the pressure constant after the temperature is raised to a preset temperature, keeping the temperature according to planned time (24 h, 36h, 48h and the like), recording the amount of oil separated out every day, and calculating the imbibition efficiency.
c. Alternate water injection imbibition method: and the alternate water injection and imbibition means that a conventional displacement device is utilized, a saturated oil and aged rock core is transferred into a rock core holder according to the conventional experiment requirements, the experiment device is installed in a thermostat, the sealing is good, after the temperature is adjusted to the formation temperature and is stable, water drive is started and driven until the water content is more than 98%, the oil output is recorded, and the water drive recovery ratio is calculated. Then 0.1-0.3PV of imbibition agent and 0.1-0.3PV of stratum simulation water are injected at the speed of 0.01-0.05mL/min, the temperature is kept for a certain time (24-n hours), the oil output is recorded and the imbibition efficiency is calculated, namely a period, and 1-n periods, generally 1-3 periods, can be carried out according to the needs. The recovery ratio of water flooding is recorded separately, the result of agent/water alternate injection and heat preservation is the imbibition efficiency of one period of dynamic imbibition of the imbibition agent, and the total imbibition efficiency is the algebraic sum of the imbibition efficiencies of a plurality of imbibition periods. The total recovery ratio of each core is the sum of the water flooding recovery ratio and the total imbibition efficiency.
(3) Calculation of imbibition efficiency
The imbibition effect is represented by the static imbibition efficiency of oil sands or a core and the dynamic imbibition efficiency of the core, wherein the core imbibition efficiency = (volume of precipitated oil/original volume value of saturated crude oil in the core) × 100%, and the oil sands imbibition efficiency = (volume of precipitated oil × density of crude oil × mass ratio of oil sands to oil mass/mass of oil sands) × 100%.
The preferred embodiments of the present invention have been described in detail, however, the present invention is not limited to the specific details of the above embodiments, and various simple modifications may be made to the technical solution of the present invention within the technical idea of the present invention, and these simple modifications are within the protective scope of the present invention.
It should be noted that, in the above embodiments, the various features described in the above embodiments may be combined in any suitable manner, and in order to avoid unnecessary repetition, the present invention does not separately describe various possible combinations.
Claims (8)
1. A fracturing fluid oil displacement agent is characterized in that: the preparation raw materials of the fracturing fluid oil displacement agent comprise the following components in parts by weight: 6-10 parts of fatty alcohol-polyoxyethylene ether, 3-5 parts of anionic surfactant, 0.5-1 part of pH regulator and 30-50 parts of deionized water.
2. The fracturing fluid oil displacement agent of claim 1, wherein: the type of the fatty alcohol-polyoxyethylene ether is AEO-7.
3. The fracturing fluid oil displacement agent of claim 1, wherein: the anionic surfactant is dodecyl benzene sulfonate.
4. The fracturing fluid oil displacement agent of claim 3, wherein: the dodecyl benzene sulfonate is sodium dodecyl benzene sulfonate.
5. The fracturing fluid oil displacement agent of claim 1, wherein: the pH regulator is metal hydroxide.
6. The fracturing fluid oil displacement agent according to claim 5, wherein: the metal hydroxide is sodium hydroxide.
7. The fracturing fluid oil displacement agent of any one of claims 1 to 6, wherein: the fracturing fluid oil displacement agent comprises the following raw materials in parts by weight: 8 parts of fatty alcohol-polyoxyethylene ether, 4 parts of anionic surfactant, 0.8 part of pH regulator and 40 parts of deionized water.
8. A fracturing fluid, characterized by: the preparation raw material of the fracturing fluid comprises the fracturing fluid oil displacement agent as defined in any one of claims 1 to 7.
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2023
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| US4016932A (en) * | 1975-12-24 | 1977-04-12 | Texaco Inc. | Surfactant oil recovery method for use in high temperature formations containing water having high salinity and hardness |
| CN105018064A (en) * | 2015-07-01 | 2015-11-04 | 西南石油大学 | Foam oil-displacing agent for high salinity and ultra-low permeability or tight oil reservoirs |
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