CN111303854B - Sandstone reservoir permeability agent, permeability fracturing fluid and use method thereof - Google Patents
Sandstone reservoir permeability agent, permeability fracturing fluid and use method thereof Download PDFInfo
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Abstract
The invention discloses a sandstone reservoir permeability agent, a phase permeability fracturing fluid and a using method thereof, wherein the sandstone reservoir permeability agent is prepared from alkyl trimethyl ammonium chloride, quaternary ammonium salt cation fluorocarbon surfactant, alkyl alkoxy carboxyl betaine, mannitol erythritol ester and organic alcohol in a proportion of (10-15): (16-25): (12-20): (15-25): 100 by mass ratio. The sandstone reservoir permeability agent provided by the invention takes alkyl trimethyl ammonium chloride, quaternary ammonium salt cation fluorocarbon surfactant, alkyl alkoxy carboxyl betaine, mannitol erythritol ester and organic alcohol as raw materials, and each component has synergistic effect, so that the sandstone surface can be converted from oil wetting into water wetting, and the oil phase permeability is improved; meanwhile, the problems of more water output and less oil output of the water injection benefit well can be solved, and the crude oil recovery rate is improved; the water control and oil increase after fracturing can be realized; meanwhile, the utility model also has the characteristic of convenient use.
Description
Technical Field
The invention relates to the technical field of oil and gas field exploitation, in particular to a sandstone reservoir permeability agent, a permeability fracturing fluid and a using method thereof.
Background
Generally, an oil layer contains certain formation water, so that oil and water are easily produced simultaneously in the oil field development process, the crude oil contains water, the oil phase permeability is reduced, and the crude oil recovery rate is low. In addition, the recovery of formation water reduces the formation energy and is not beneficial to oil and gas development. In the middle and later stages of oil field development, produced water is gradually increased, produced oil is gradually reduced, even part of oil can not be extracted, and stratum energy needs to be kept by means of water injection and the like so as to improve the crude oil recovery rate.
Fracturing is widely used as an important stimulation tool for oil and gas fields. The fracturing is a technological measure that a high-viscosity fracturing fluid is pumped into a well by utilizing a ground high-pressure pump group at a discharge capacity exceeding the liquid absorption capacity of a stratum, when the pumped discharge capacity is larger than the liquid absorption capacity of the stratum, the stratum generates cracks, the fracturing fluid is continuously injected to enable hydraulic cracks to gradually extend, then a sand mixing fluid with a propping agent is injected to enable the hydraulic cracks to continuously extend and fill the propping agent in the cracks, and after the pump is stopped, sand filling cracks with enough length and enough width are formed in the stratum due to the propping effect of the propping agent on the cracks, so that the yield increase of an oil-gas well and the injection increase of a water injection well are realized. In the fracturing process, along with the extension of the crack, the crack is easy to communicate with a reservoir area with high water saturation and even a water layer, so that the oil phase permeability is easy to reduce, and especially for low-permeability oil reservoirs, the oil phase permeability is obviously reduced.
The above problems are one of the key problems restricting oilfield development, and the main reason for these problems is that the problems of formation wettability, i.e. oil phase permeability and water phase permeability, are not well solved.
Disclosure of Invention
The invention aims to overcome the technical defects, provides a sandstone reservoir permeability agent, a permeability fracturing fluid and a using method thereof, and solves the technical problems of low permeability of sandstone reservoir oil phase, unsatisfactory water injection and oil increasing effects and serious water production after fracturing in the prior art.
In order to achieve the technical purpose, the first aspect of the invention provides a sandstone reservoir permeability agent, which is prepared from alkyl trimethyl ammonium chloride, quaternary ammonium salt cationic fluorocarbon surfactant, alkyl alkoxy carboxyl betaine, mannitol erythritol ester and organic alcohol in a proportion of (10-15): (16-25): (12-20): (15-25): 100 by mass ratio.
The second aspect of the invention provides a phase-cementation fracturing fluid which is prepared from a thickening agent, a bactericide, a phase-cementation agent, a clay stabilizer, a cross-linking agent, a gel breaker and water, wherein the weight ratio of the thickening agent to the bactericide to the phase-cementation agent is (0.2-0.6): (0.01-0.05): (0.1-0.3): (0.5-2): (0.02-0.3): (0.002-0.01) and 100 in mass ratio; the permeability agent is the permeability agent for the sandstone reservoir provided by the first aspect of the invention.
In a third aspect, the invention provides a method of using the permeability agent, which comprises a single use method, a water injection use method and a combined permeability fracturing fluid use method. Wherein the permeability agent is the permeability agent for sandstone reservoirs provided by the first aspect of the invention.
Compared with the prior art, the invention has the beneficial effects that:
the sandstone reservoir permeability agent provided by the invention takes alkyl trimethyl ammonium chloride, quaternary ammonium salt cation fluorocarbon surfactant, alkyl alkoxy carboxyl betaine, mannitol erythritol ester and organic alcohol as raw materials, and each component has synergistic effect, so that the sandstone surface can be converted from oil wetting into water wetting, and the oil phase permeability is improved; meanwhile, the problems of more water output and less oil output of the water injection benefit well can be solved, and the crude oil recovery rate is improved; the water control and oil increase after fracturing can be realized; meanwhile, the utility model also has the characteristic of convenient use.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the present invention is further described in detail with reference to the following embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the invention and are not intended to limit the invention.
The invention provides a sandstone reservoir permeability agent, which is prepared from (10-15) alkyl trimethyl ammonium chloride, a quaternary ammonium salt cationic fluorocarbon surfactant, alkyl alkoxy carboxyl betaine, mannosylerythritol ester and organic alcohol: (16-25): (12-20): (15-25): 100 by mass ratio.
The organic active substance contained in the crude oil wets the stratum rock for billions of years, so that the stratum rock becomes oleophilic or weakly oleophilic, namely, the crude oil and the stratum rock are in a complete wetting state or a wetting state, and the contact angle is small. The capillary pressure equation is: p is 2 γ cos θ/r, wherein γ is the surface tension; theta is a contact angle; r is the capillary radius. According to a capillary pressure formula, the contact angle is small, the capillary pressure is large, and therefore the flow of crude oil in the pores of formation rock is hindered, and the oil phase permeability is low.
In the phase permeation agent, alkyl trimethyl ammonium chloride and quaternary ammonium salt cation fluorocarbon surfactant are cation surfactants, automatically enter the deep part of a sandstone stratum through the permeation action, are adsorbed on the surface of rock to form a monomolecular adsorption film through the physical and chemical action, have poor adsorption capacity and mainly play a role in permeation. The alkyl trimethyl ammonium chloride has strong permeability, the quaternary ammonium salt cation fluorocarbon surfactant has strong capability of reducing surface/interface tension, and the two are synergistic, so that the imbibition capability can be obviously improved. The alkyl alkoxy carboxyl betaine is a zwitterionic surfactant, has an electrostatic adsorption effect with the surface of sandstone, and can form hydrogen bonds through the action of alkoxy and carboxyl in the molecule and hydroxyl on the surface of rock, so that the adsorption density (namely the adsorption effect) with the surface of sandstone is further increased, bimolecular adsorption is formed, and the scouring resistance of the surfactant is further improved. The mannose erythritol ester is adsorbed on the surface of the sandstone due to the special molecular structure of the mannose erythritol ester, so that a strong hydrophilic surface is formed on the surface of the sandstone, a contact angle is increased, and oil wetting is changed into water wetting; meanwhile, the quaternary ammonium salt cation fluorocarbon surfactant has strong capability of reducing surface/interface tension, and the capillary pressure is reduced together by the mutual synergistic action of the mannose erythritol ester and the quaternary ammonium salt cation fluorocarbon surfactant according to a capillary pressure formula.
In the formula of the phase permeation agent, alkyl trimethyl ammonium chloride, quaternary ammonium salt cationic fluorocarbon surfactant, alkyl alkoxy carboxyl betaine, mannitol erythritol ester and organic alcohol respectively play roles and are mutually cooperated, and finally, the remarkable effect is achieved.
Preferably, the alkyl trimethyl ammonium chloride is one or more of dodecyl trimethyl ammonium chloride, tetradecyl trimethyl ammonium chloride and hexadecyl trimethyl ammonium chloride.
Preferably, the quaternary ammonium salt cationic fluorocarbon surfactant is one or more of an octaalkyl quaternary ammonium salt cationic fluorocarbon surfactant, a dodecyl quaternary ammonium salt cationic fluorocarbon surfactant and a dodecyl quaternary ammonium salt cationic fluorocarbon surfactant.
Specifically, the quaternary ammonium salt cationic fluorocarbon surfactant has the structure as follows:
wherein R is-C8H17，-C10H21，-C12H25One or more of them.
Research shows that the fluorine-containing surfactant has stronger capability of reducing surface/interface tension, but has certain toxicity. It is generally considered that the fluorocarbon chain length is 4 or less, which is less harmful to the environment. Therefore, the quaternary ammonium salt cationic fluorocarbon surfactant with the fluorocarbon chain length of 3 is selected in the invention. In addition, the amide group reacts with the hydroxyl on the surface of the rock to form a hydrogen bond, so that the adsorption density is improved, and the adsorption capacity is improved.
Preferably, the alkyl alkoxy carboxyl betaine is one or more of dodecyl alkoxy carboxyl betaine and tetradecyl alkoxy carboxyl betaine.
Specifically, the alkyl alkoxy carboxyl betaine has a structural formula as follows:
wherein R is-C12H25，-C14H29One or more of them.
Preferably, the organic alcohol is one or more of methanol, ethanol and propanol. Further, the organic alcohol is methanol.
Preferably, the sandstone reservoir permeability agent is obtained by the following steps: weighing the raw materials according to the proportion, adding alkyl trimethyl ammonium chloride, quaternary ammonium salt cation fluorocarbon surfactant, alkyl alkoxy carboxyl betaine and mannose erythritol lipid into organic alcohol, and uniformly mixing to obtain the sandstone reservoir permeability agent.
The second aspect of the invention provides a phase-cementation fracturing fluid which is prepared from a thickening agent, a bactericide, a phase-cementation agent, a clay stabilizer, a cross-linking agent, a gel breaker and water, wherein the weight ratio of the thickening agent to the bactericide to the phase-cementation agent is (0.2-0.6): (0.01-0.05): (0.1-0.3): (0.5-2): (0.02-0.3): (0.002-0.01) and 100 in mass ratio; the permeability agent is the permeability agent for the sandstone reservoir provided by the first aspect of the invention.
According to the invention, the phase-permeation fracturing fluid is obtained by compounding the thickening agent, the bactericide, the phase-permeation agent, the clay stabilizer, the cross-linking agent, the gel breaker and water according to the mass ratio, and compared with the conventional fracturing fluid, the obtained phase-permeation fracturing fluid improves the adsorption performance of the fracturing fluid on the surface of a sandstone oil reservoir, changes the wettability of the sandstone surface, changes the oil-wetting property of the sandstone surface into the water-wetting property, and improves the oil-phase permeability after fracturing.
Preferably, the thickening agent is one or more of guar gum, hydroxypropyl guar gum and carboxymethyl hydroxypropyl guar gum.
Preferably, the bactericide is glutaraldehyde.
Preferably, the clay stabilizer is one or more of potassium chloride and ammonium chloride.
Preferably, the crosslinking agent is one or more of borax, an organic boron crosslinking agent, an organic titanium crosslinking agent and an organic zirconium crosslinking agent.
Preferably, the gel breaker is one or more of ammonium persulfate and potassium persulfate.
Preferably, the phase-cementation fracturing fluid is obtained by the following steps: weighing the raw materials according to the proportion, mixing water and a thickening agent, then adding a bactericide, a phase permeation agent and a clay stabilizer for continuous mixing, and finally adding a gel breaker and a crosslinking agent for uniform mixing to obtain the phase permeation fracturing fluid.
In a third aspect, the invention provides a method of using the permeability agent, which comprises a single use method, a water injection use method and a combined permeability fracturing fluid use method. Wherein the permeability agent is the permeability agent for sandstone reservoirs provided by the first aspect of the invention.
Specifically, the steps of the single use method are: injecting a permeability agent into the stratum according to the volume of 1-5 times of the thickness of the fracturing layer, wherein the injection discharge capacity is 0.5-1 m3And/min, after the injection is finished, injecting a displacement liquid with the volume of the shaft, completely injecting the phase permeation agent into the stratum, closing the well for 2-5 hours, finishing the construction, and normally opening the well for production.Wherein, the displacement fluid is a completion fluid, is generally 2% potassium chloride water solution, and can also be prepared according to the field requirement.
The phase penetrating agent provided by the invention is used independently, and through the synergistic effect of the components of the phase penetrating agent, the surface/interface tension is reduced, the contact angle between kerosene and a rock core is increased, oil wetting is converted into water wetting, and finally the oil phase permeability is improved; and the adsorption capacity of the phase permeation agent and the rock core is improved through the action of the phase permeation agent, so that the scouring resistance of the phase permeation agent is improved, and finally the reduction rate of the oil phase permeability is low.
Specifically, the water injection using method comprises the following steps: in the process of oilfield water injection, a phase permeation agent is added into oilfield injection water according to the proportion of (0.1-0.5) to 100. The oilfield injection water can be seawater, formation water, oilfield return water treatment water and the like which reach the oilfield injection water standard.
The water injection using method of the phase penetrating agent provided by the invention has the advantages that through the synergistic effect of the components of the phase penetrating agent, the surface/interface tension is reduced, the contact angle between kerosene and a rock core is increased, the oil phase permeability is improved, the water phase permeability is reduced, the problems of more water output and less oil output of a water injection benefited well are solved, the water control and oil increase are realized, and the crude oil recovery ratio is improved.
Specifically, the combined phase-cementation fracturing fluid using method comprises the following steps: before fracturing construction, injecting a phase penetrating agent into the stratum according to the volume of 1-3 times of the thickness of the fracturing layer, wherein the injection discharge capacity is 0.5-1 m3Injecting a displacement liquid with the volume of a shaft after injection is finished, completely injecting a phase permeation agent into the stratum, and closing the well for 1-2 hours; and during fracturing construction, injecting a phase-permeation fracturing fluid according to the fracturing design requirement, then injecting a displacement fluid, and finishing the construction. Wherein, the displacement fluid is a completion fluid, is generally 2% potassium chloride water solution, and can also be prepared according to the field requirement.
The phase seepage fracturing fluid used in the combined phase seepage fracturing fluid use method can be a phase seepage fracturing fluid in the prior art and can also be the phase seepage fracturing fluid provided by the invention. Preferably the phase-permeation fracturing fluid provided by the invention.
The method for jointly using the permeability agents reduces surface/interface tension and increases the contact angle between kerosene and a rock core through the synergistic effect of the components of the permeability agents, improves the permeability of the oil phase of the sandstone after fracturing, reduces the permeability of the water phase, realizes water control and oil increase, and solves the problems of serious water outlet and low permeability of the oil phase caused by fracturing and communicating a reservoir area or a water layer with high water saturation. Therefore, when the reservoir with high water saturation is communicated in the fracturing process, even after the reservoir is communicated with a water layer, a large amount of water does not flow out, and the effects of controlling water and increasing oil can be achieved.
Example 1
The embodiment provides a penetrant, which is prepared from dodecyl trimethyl ammonium chloride, dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine, mannosylerythritol ester and methanol according to the weight ratio of 10: 16: 12:15: 100 by mass ratio.
The preparation method specifically comprises the following steps: weighing the raw materials according to the proportion, adding dodecyl trimethyl ammonium chloride, dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine and mannosylerythritol lipid into methanol, and uniformly mixing to obtain the phase permeation agent.
Example 2
The embodiment provides a penetrant, which is prepared from dodecyl trimethyl ammonium chloride, dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine, mannosylerythritol ester and methanol according to the weight ratio of 15: 25: 20: 25: 100 by mass ratio.
The preparation method specifically comprises the following steps: weighing the raw materials according to the proportion, adding dodecyl trimethyl ammonium chloride, dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine and mannosylerythritol lipid into methanol, and uniformly mixing to obtain the phase permeation agent.
Example 3
The embodiment provides a penetrant, which is prepared from dodecyl trimethyl ammonium chloride, dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine, mannosylerythritol ester and methanol according to the weight ratio of 12:20:15: 20:100 by mass ratio.
The preparation method specifically comprises the following steps: weighing the raw materials according to the proportion, adding dodecyl trimethyl ammonium chloride, dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine and mannosylerythritol lipid into methanol, and uniformly mixing to obtain the phase permeation agent.
Example 4
The embodiment provides a phase-permeation fracturing fluid which is prepared from hydroxypropyl guar gum, glutaraldehyde, a phase permeation agent, potassium chloride, borax, ammonium persulfate and water in a weight ratio of 0.2: 0.01: 0.1: 0.5: 0.02: 0.01:100 by mass ratio.
The preparation method specifically comprises the following steps: weighing the raw materials according to the proportion, adding water into a mixing and adjusting device, adjusting the mixing and adjusting device to 2000 r/min, adding hydroxypropyl guar gum, stirring for 300 seconds, then adding glutaraldehyde, a phase permeation agent and potassium chloride, and continuing stirring for 30 seconds; then ammonium persulfate and borax are added, and the mixture is continuously stirred for 30 seconds to prepare the phase-permeation fracturing fluid. Wherein, the actual borax added into the system is 2 parts of borax water solution with the mass fraction of 1%, so that the actual effective concentration of the borax in the system is 0.02%.
The isotonic agent used in this example was the one prepared in example 1.
Example 5
The embodiment provides a phase-permeation fracturing fluid which is prepared from hydroxypropyl guar gum, glutaraldehyde, a phase permeation agent, potassium chloride, borax, ammonium persulfate and water in a weight ratio of 0.4: 0.05: 0.3: 2: 0.03: 0.002:100 by mass ratio.
The preparation method specifically comprises the following steps: weighing the raw materials according to the proportion, adding water into a mixer, adjusting the mixer to 3000 r/min, adding hydroxypropyl guar gum, stirring for 300 seconds, then adding glutaraldehyde, a phase permeation agent and potassium chloride, and continuing stirring for 30 seconds; then ammonium persulfate and borax are added, and the mixture is continuously stirred for 30 seconds to prepare the phase-permeation fracturing fluid. Wherein, the actual borax added into the system is 3 parts of borax water solution with the mass fraction of 1%, so that the actual effective concentration of the borax in the system is 0.03%.
The isotonic agent used in this example was the one prepared in example 2.
Example 6
The embodiment provides a phase-permeation fracturing fluid which is prepared from hydroxypropyl guar gum, glutaraldehyde, a phase permeation agent, potassium chloride, borax, ammonium persulfate and water in a proportion of 0.3: 0.02: 0.2: 1: 0.025: 0.005:100 by mass ratio.
The method comprises the following specific steps: weighing the raw materials according to the proportion, adding water into a mixer, adjusting the mixer to 2500 rpm, adding hydroxypropyl guar gum, stirring for 300 seconds, then adding glutaraldehyde, a phase permeation agent and potassium chloride, and continuing stirring for 30 seconds; then ammonium persulfate and borax are added, and the mixture is continuously stirred for 30 seconds to prepare the phase-permeation fracturing fluid. Wherein, the actual amount of the borax added into the system is 2.5 parts of borax water solution with the mass fraction of 1%, and the actual effective concentration of the borax in the system is 0.025%.
The isotonic agent used in this example was the one prepared in example 3.
Example 7
The embodiment provides a using method of a phase permeation agent, which is a single using method, and adopts the phase permeation agent prepared in the embodiment 1, and the specific steps are as follows; volume 2 times the thickness of the fracturing layer (19.2 m)3) Injecting a permeability agent into the stratum with the injection discharge capacity of 0.5m3Min, after injection, a wellbore volume (10.6 m) is injected again3) And (4) displacing the liquid, completely injecting the phase permeation agent into the stratum, closing the well for 2.5 hours, finishing the construction, and normally opening the well for production.
Example 8
The embodiment provides a using method of a phase permeation agent, which is a single using method, adopts the phase permeation agent prepared in the embodiment 2, and comprises the following specific steps; volume 3.5 times the thickness of the fracturing layer (18.2 m)3) Injecting a permeability agent into the stratum with the injection discharge capacity of 0.8m3Min, after injection, a wellbore volume (12.9 m) is injected again3) And (4) displacing the liquid, completely injecting the phase permeation agent into the stratum, closing the well for 4 hours, finishing the construction, and normally opening the well for production.
Example 9
The embodiment provides a using method of a phase permeation agent, which is a single using method, and adopts the phase permeation agent prepared in the embodiment 3, and the specific steps are as follows; press 5 times of voltageThickness of the cracked layer (31.5 m)3) Injecting a phase penetrating agent into the stratum with the injection discharge capacity of 1m3Min, after injection, a wellbore volume (17.3 m) is injected again3) And (4) displacing the liquid, completely injecting the phase permeation agent into the stratum, closing the well for 5 hours, finishing the construction, and normally opening the well for production.
Example 10
The embodiment provides a using method of a phase permeation agent, which is a water injection using method, and adopts the phase permeation agent prepared in the embodiment 1, and the specific steps are as follows;
in the process of oilfield flooding, the phasic osmotic agent prepared in example 1 was added to oilfield flooding water, which was seawater, in a ratio of 0.1:100 to prepare phasic osmotic flooding water.
Example 11
The embodiment provides a using method of a phase permeation agent, which is a water injection using method, and adopts the phase permeation agent prepared in the embodiment 2, and the specific steps are as follows;
in the process of oilfield flooding, the phasic osmotic agent prepared in example 2 was added to oilfield flooding water, which was seawater, in a ratio of 0.5:100 to prepare phasic osmotic flooding water.
Example 12
The embodiment provides a using method of a phase permeation agent, which is a water injection using method, and adopts the phase permeation agent prepared in the embodiment 3, and the specific steps are as follows;
in the oilfield flooding process, the phasic osmotic agent prepared in example 3 was added to oilfield flooding water, which was seawater, in a ratio of 0.2:100 to prepare phasic osmotic flooding water.
Example 13
The embodiment provides a using method of a phase permeation agent, which is a combined phase permeation fracturing fluid using method, and the specific steps of the phase permeation agent prepared in the embodiment 1 and the phase permeation fracturing fluid prepared in the embodiment 4 are as follows:
before fracturing construction, the volume of the fracturing layer is 1 time of the thickness of the fracturing layer (5.7 m)3) Injecting a permeability agent into the stratum with the injection discharge capacity of 0.5m3Min, after injection, a wellbore volume (15.3 m) is injected again3) Replacing the liquid, completely injecting a phase permeation agent into the stratum, and closing the well for 1 h; when fracturing construction, 320m of the slurry is injected3Injecting 15.3m of phase-permeation fracturing fluid3And (5) replacing the liquid, and finishing construction.
Example 14
This example provides a method for using a permeability agent, which is a method for using a combined phase-permeable fracturing fluid, and the specific steps of using the permeability agent prepared in example 2 and the phase-permeable fracturing fluid prepared in example 5 are as follows:
before fracturing construction, the volume of the fracturing layer is 3 times of the thickness of the fracturing layer (21.3 m)3) Injecting a permeability agent into the stratum with the injection displacement of 1m3Min, after injection, a wellbore volume (17.9 m) is injected again3) Displacing the liquid, completely injecting a phase permeation agent into the stratum, and closing the well for 2 hours; during the fracturing construction, 350m of the slurry is injected3Injecting 17.9m of phase-permeation fracturing fluid3And (5) replacing the liquid, and finishing construction.
Example 15
This example provides a method for using a permeability agent, which is a method for using a combined phase-permeable fracturing fluid, and the specific steps of using the permeability agent prepared in example 3 and the phase-permeable fracturing fluid prepared in example 6 are as follows:
before fracturing construction, the volume of 2 times of the thickness of the fracturing layer (6.6 m)3) Injecting a permeability agent into the stratum with the injection discharge capacity of 0.6m3Min, after injection, a further wellbore volume (21.7 m) was injected3) Displacing the liquid, completely injecting a phase permeation agent into the stratum, and closing the well for 1.5 hours; when fracturing is carried out, 230m of the fracturing fluid is injected3Injecting the fracturing fluid into the fracturing fluid of 21.7m3And (5) replacing the liquid, and finishing construction.
Comparative example 1
The process is the same as example 3 except that the process is carried out by compounding dodecyl trimethyl ammonium chloride and methanol at a mass ratio of 12: 100.
Comparative example 2
The same as example 3, except that the surfactant was prepared by mixing only a decaalkyl quaternary ammonium salt cationic fluorocarbon surfactant and methanol at a mass ratio of 20: 100.
Comparative example 3
The procedure was as in example 3 except that the above-mentioned compound was prepared from tetradecylalkoxycarboxybetaine and methanol at a mass ratio of 15: 100.
Comparative example 4
The procedure was as in example 3 except that only mannosylerythritol lipids and methanol were compounded at a mass ratio of 20: 100.
Comparative example 5
Methanol alone.
Comparative example 6
The composition is the same as that in example 3 except that the composition is prepared by only mixing decaalkyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine, mannitol erythritol ester and methanol in a mass ratio of 20:15:20: 100.
Comparative example 7
The procedure is as in example 3 except that the aqueous dispersion is prepared by mixing dodecyl trimethyl ammonium chloride, tetradecyl alkoxy carboxyl betaine, mannosylerythritol ester and methanol at a mass ratio of 12:15:20: 100.
Comparative example 8
The composition is the same as that in example 3 except that the composition is prepared by only compounding dodecyl trimethyl ammonium chloride, a dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, mannitol erythritol ester and methanol in a mass ratio of 12:20:20: 100.
Comparative example 9
The composition is the same as that in example 3 except that the composition is prepared by only compounding dodecyl trimethyl ammonium chloride, a dodecyl quaternary ammonium salt cationic fluorocarbon surfactant, tetradecyl alkoxy carboxyl betaine and methanol in a mass ratio of 12:20:15: 100.
Test group 1
The contact angle test was performed on the rock pieces treated with the working solutions obtained in examples 1 to 3 and comparative examples 1 to 9, and the blank control was a 2% potassium chloride aqueous solution. The test results are shown in Table 1.
The processing of the rock slices is as follows:
1) preparation of rock slices
And drilling a rock core, wherein the diameter of the rock core is 25.4mm, and then cutting the rock core into rock slices with the length of 5-30 mm to obtain the rock slices with the diameter of 25.4mm and the length of 5-30 mm.
2) Saturated vacuumizing and soaking of rock slices
And under the condition of vacuumizing, the rock slice is saturated with working fluid.
3) Contact Angle determination
The contact angle of kerosene on the rock was measured using a contact angle measuring instrument.
TABLE 1 contact Angle measurement
| Working fluid | Contact angle (°) |
| Example 1 | 156 |
| Example 2 | 147 |
| Example 3 | 152 |
| Blank control group | 22 |
| Comparative example 1 | 18 |
| Comparative example 2 | 65 |
| Comparative example 3 | 53 |
| Comparative example 4 | 112 |
| Comparative example 5 | 52 |
| Comparative example 6 | 132 |
| Comparative example 7 | 124 |
| Comparative example 8 | 128 |
| Comparative example 9 | 107 |
As can be seen from Table 1, the contact angles of the rock slices treated by the phase permeation liquid obtained in examples 1-3 and kerosene are all larger than 140 degrees, while the contact angle of the rock slices treated by the 2% potassium chloride aqueous solution and kerosene is only 22 degrees, which shows that the phase permeation agent provided by the invention can remarkably improve the contact angle of the rock slices and kerosene.
The contact angle of the rock slice treated by the solutions in comparative examples 2-9 and kerosene is between 52 degrees and 132 degrees, and compared with a blank control group, the contact angle is improved to a certain degree, but the high oleophobic effect achieved by the invention can not be achieved, which indicates that the synergistic effect of each component in the phase permeation agent is required when the contact angle is increased, and the effect can not be achieved if a certain component is lacked.
Test group 2
The rock pieces treated by the working solutions obtained in examples 1 to 3 and comparative examples 5 to 9 were subjected to an oil phase permeability test, and the blank control was a 2% potassium chloride aqueous solution. The test results are shown in Table 2.
The treatment process of the core is as follows:
1) preparation and treatment
Cores were drilled with a size of 25.4 x 50.8mm, i.e. 25.4mm diameter and 50.8mm length. Washing oil and salt, drying at 60 ℃ to constant weight, and measuring the pore volume of the rock core.
2) Oil phase Permeability determination
Then, the core was placed in a core holder, and the static confining pressure of 5MP was kept constant.
A) Oil phase Permeability determination before treatment
Positive displacement of kerosene, determination of oil phase permeability K before treatment0。
B) Oil phase Permeability measurement after treatment
After the oil phase permeability measurement before treatment is finished, reversely displacing the working fluid, stopping displacing when the working fluid with 5 times of the pore volume is displaced from the other end of the rock core, and standing for 2 hours;
positive displacement kerosene, and measuring oil phase permeability K of the rock core treated by different working fluids under 1h, 6h and 8htt。
The oil phase permeability improvement rate is calculated by the following formula:
n＝(Ktt-K0)/k0*100％。
in addition, along with the displacement, the working solution is gradually desorbed from the surface of the rock core, so that the oil phase permeability is slowly reduced, and in order to evaluate the scouring resistance of the working solution on the surface of the rock core, the reduction rate of the oil phase permeability after treatment for 1-8 h is calculated by adopting the following formula:
w＝(Kt8-kt1)/Kt1*100％。
wherein, Kt1Oil phase Permeability after 1h of treatment, Kt6Oil phase Permeability after 6h of treatment, Kt8The oil phase permeability after 8h of treatment.
TABLE 2 oil phase Permeability and Rate of improvement
As can be seen from Table 2, the samples treated with the phase-permeation solutions obtained in examples 1 to 3 have a high oil phase permeability improvement rate and a low treated oil phase permeability reduction rate. Compared with example 3, the oil phase permeability improvement rate of comparative example 6 is lower, and the oil phase permeability reduction rate after treatment is higher, because alkyl trimethyl ammonium chloride is not added in comparative example 6, the alkyl trimethyl ammonium chloride loses the strong permeability brought by the alkyl trimethyl ammonium chloride, cannot enter the interior of the rock slice, and cannot perform a synergistic effect with other components, so that the oil phase permeability improvement rate is lower and the oil phase permeability reduction rate after treatment is higher. Compared with example 3, the oil phase permeability of comparative example 7 is lower in improvement rate and higher in reduction rate of oil phase permeability after treatment, because the quaternary ammonium salt cationic fluorocarbon surfactant is not added in comparative example 7, the surface/interface tension reduction effect caused by the quaternary ammonium salt cationic fluorocarbon surfactant is lost, and the synergistic effect with other components cannot be achieved, so that the contact angle and the oil phase permeability are lower in improvement rate and the oil phase permeability reduction rate after treatment is higher. Compared with example 3, comparative example 8 has a lower oil phase permeability improvement rate and an extremely high oil phase permeability reduction rate after treatment, because alkyl alkoxy carboxyl betaine is not added in comparative example 8, and loses the strong adsorption capacity of the alkyl alkoxy carboxyl betaine to sandstone, so that the working fluid and the sandstone have poor adsorption capacity and are not resistant to scouring, and the oil phase permeability reduction rate after treatment is high along with the displacement, and meanwhile, the oil phase permeability improvement rate cannot be synergistic with other components, so that the oil phase permeability improvement rate is lower. Comparative example 9 has an extremely low rate of increase in oil phase permeability and a higher rate of decrease in oil phase permeability after treatment, compared to example 3, because no mannosylerythritol ester is added to comparative example 9, which loses its ability to coordinate with the quaternary ammonium salt cationic fluorocarbon surfactant, resulting in a lower contact angle and an extremely low rate of increase in oil phase permeability; meanwhile, the oil phase permeability can not be synergistically acted with other components, so that the reduction rate of the oil phase permeability after treatment is high.
Test group 3
The oil displacement effect of the cores treated by the working fluids obtained in examples 1 to 3 and comparative examples 6 to 9 was tested, the blank control group was a 2% potassium chloride aqueous solution, and the test results are shown in table 3.
The treatment process is as follows:
1) preparation of phase-permeation injection water
The solutions in examples 1-3, comparative examples 5-9 and the blank control were added to seawater in a mass ratio of 0.2:100 to make phase-bleed water. The samples were designated as example 1 (water injection), example 2 (water injection), example 3 (water injection), blank control (water injection), comparative example 5 (water injection), comparative example 6 (water injection) to comparative example 9 (water injection).
2) Preparation of cores and treatment
Cores were drilled with a size of 25.4 x 50.8mm, i.e. 25.4mm diameter and 50.8mm length. And (4) washing oil and salt of the rock core, and drying at 60 ℃ to constant weight.
3) Recovery Rate of oil recovery
A) Under the condition of vacuumizing, the core is subjected to kerosene saturation, and the oil content V is measuredFront 0. Then putting the core into a core holder, keeping the static confining pressure of 5MP unchanged, displacing the core by using seawater, displacing the displacement volume of 1mL/min, and measuring the volume V of oil displaced for 6hFront 1Then calculating the pre-treatment recovery factor nFront sideAnd calculating a formula: n isFront side＝VFront 1/VFront 0。
B) After the experiment A) is finished, the rock core is taken out, under the condition of vacuumizing, the rock core is subjected to kerosene saturation, and the oil content V is measuredRear 0. Then putting the core into a core holder, keeping the static confining pressure of 5MP unchanged, displacing the core by using phase-permeation injection water, measuring the volume V of oil displaced for 6h, wherein the displacement is 1mL/minRear 1And then calculating the recovery factor n before treatment according to the formula: n isRear end＝VRear 1/VRear 0。
C) Calculating the recovery ratio W ═ n by formulaRear end-nFront side)/nFront side*100％。
TABLE 3 recovery and recovery enhancement
| Pre-treatment recovery | Recovery after treatment | Rate of increase of recovery | |
| Example 1 (Water injection) | 14％ | 22％ | 55％ |
| Example 2 (Water injection) | 16％ | 24％ | 53％ |
| Example 3 (Water injection) | 15％ | 24％ | 59％ |
| Blank control group (Water injection) | 13％ | 14％ | 5％ |
| Comparative example 5 (Water injection) | 14％ | 18％ | 28％ |
| Comparative example 6 (Water injection) | 16％ | 23％ | 42％ |
| Comparative example 7 (Water injection) | 13％ | 19％ | 45％ |
| COMPARATIVE EXAMPLE 8 (Water injection) | 14％ | 20％ | 44％ |
| COMPARATIVE EXAMPLE 9 (Water injection) | 15％ | 20％ | 36％ |
As can be seen from table 3, the recovery efficiencies of example 1 (injected water), example 2 (injected water) and example 3 (injected water) were 53% or more, while the recovery efficiencies of 2% potassium chloride aqueous solution (injected water) were 5% and the recovery efficiencies of comparative examples 6 (injected water) to 9 (injected water) were 45% or less, indicating that the water control and oil enhancement and the recovery efficiency enhancement can be achieved by adding the phase permeation agent of the present invention to the injected water. Compared with the phase penetrating agent, other working solutions have poorer effects, and further illustrate that the effect of the phase penetrating agent is realized by the joint synergistic effect of all the components, and the effect cannot be achieved by the absence of a certain component.
In conclusion, the phase permeation agent provided by the invention takes alkyl trimethyl ammonium chloride, quaternary ammonium salt cationic fluorocarbon surfactant, alkyl alkoxy carboxyl betaine, mannose erythritol ester and organic alcohol as raw materials, and all the components have synergistic effect, so that oil wetting can be converted into water wetting, the oil phase permeability is improved, the problems of more water output and less oil output of a water injection benefited well are solved, the crude oil recovery rate is improved, and water control and oil increase can be realized after fracturing; meanwhile, the preparation method is simple and the use is convenient.
The above description is only for the purpose of illustrating the preferred embodiments of the present invention and is not to be construed as limiting the invention, and any modifications, equivalents, improvements and the like that fall within the spirit and principle of the present invention are intended to be included therein.
Claims (9)
1. The sandstone reservoir permeability agent is characterized by comprising the following components in parts by weight: (16-25): (12-20): (15-25): 100 by mass ratio.
2. The sandstone reservoir permeability agent of claim 1, wherein the alkyltrimethylammonium chloride is one or more of dodecyltrimethylammonium chloride, tetradecyltrimethylammonium chloride, and hexadecyltrimethylammonium chloride.
3. The sandstone reservoir permeability agent of claim 1, wherein the quaternary ammonium salt cationic fluorocarbon surfactant is one or more of an octaalkyl quaternary ammonium salt cationic fluorocarbon surfactant, a decaalkyl quaternary ammonium salt cationic fluorocarbon surfactant, and a dodecyl quaternary ammonium salt cationic fluorocarbon surfactant.
4. The sandstone reservoir permeability agent of claim 1, wherein the alkyl alkoxy carboxyl betaine is one or more of dodecyl alkoxy carboxyl betaine and tetradecyl alkoxy carboxyl betaine.
5. The sandstone reservoir permeability agent of claim 1, wherein the organic alcohol is one or more of methanol, ethanol and propanol.
6. The phase-permeation fracturing fluid is characterized by comprising a thickening agent, a bactericide, a phase permeation agent, a clay stabilizer, a cross-linking agent, a gel breaker and water, wherein the weight ratio of the thickening agent to the bactericide to the phase-permeation agent to the clay stabilizer is (0.2-0.6): (0.01-0.05): (0.1-0.3): (0.5-2): (0.02-0.3): (0.002-0.01) and 100 in mass ratio; the permeability agent is the permeability agent of the sandstone reservoir of any one of claims 1 to 5.
7. The phase-permeable fracturing fluid of claim 6, wherein the thickening agent is one or more of guar gum, hydroxypropyl guar gum and carboxymethyl hydroxypropyl guar gum; the bactericide is glutaraldehyde; the clay stabilizer is one or more of potassium chloride and ammonium chloride; the cross-linking agent is one or more of borax, an organic boron cross-linking agent, an organic titanium cross-linking agent and an organic zirconium cross-linking agent; the gel breaker is one or more of ammonium persulfate and potassium persulfate.
8. A method of using the permeability agent of any one of claims 1 to 5, wherein the method of using the permeability agent comprises a single use method, a water injection use method and a combined permeability fracturing fluid use method.
9. The method of using a tonicity agent according to claim 8, wherein the steps of the separate use are: injecting a permeability agent into the stratum according to the volume of 1-5 times of the thickness of the fracturing layer, wherein the injection discharge capacity is 0.5-1 m3Injecting a displacement liquid with the volume of a shaft after injection is finished, completely injecting a phase permeation agent into the stratum, closing the well for 2-5 hours, and normally opening the well for production after construction is finished;
the water injection using method comprises the following steps: in the process of oilfield water injection, adding a phase permeation agent into oilfield injection water according to the proportion of (0.1-0.5) to 100;
steps of the combined phase cementation fracturing fluid application methodComprises the following steps: before fracturing construction, injecting a phase penetrating agent into the stratum according to the volume of 1-3 times of the thickness of the fracturing layer, wherein the injection discharge capacity is 0.5-1 m3Injecting a displacement liquid with the volume of a shaft after injection is finished, completely injecting a phase permeation agent into the stratum, and closing the well for 1-2 hours; and during fracturing construction, injecting a phase seepage fracturing fluid into the fracturing design, then injecting a displacement fluid, and finishing construction.
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| CN104531123A (en) * | 2015-01-23 | 2015-04-22 | 成都华阳兴华化工有限公司 | Foam flooding agent for thick oil and preparation method thereof |
| CN104650844A (en) * | 2013-11-22 | 2015-05-27 | 中国石油天然气股份有限公司 | Cleanup additive with high contact angle on rock core surface and preparation method thereof |
| CN108102634A (en) * | 2017-11-23 | 2018-06-01 | 中国石油天然气股份有限公司 | A kind of tight sandstone reservoir slippery water fracturing fluid and its application |
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| CN104650844A (en) * | 2013-11-22 | 2015-05-27 | 中国石油天然气股份有限公司 | Cleanup additive with high contact angle on rock core surface and preparation method thereof |
| CN104531123A (en) * | 2015-01-23 | 2015-04-22 | 成都华阳兴华化工有限公司 | Foam flooding agent for thick oil and preparation method thereof |
| CN108102634A (en) * | 2017-11-23 | 2018-06-01 | 中国石油天然气股份有限公司 | A kind of tight sandstone reservoir slippery water fracturing fluid and its application |
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