CN115449362A - Fracturing fluid for realizing high flow conductivity of artificial fractures and application method thereof - Google Patents
Fracturing fluid for realizing high flow conductivity of artificial fractures and application method thereof Download PDFInfo
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- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid group Chemical group C(CC(O)(C(=O)O)CC(=O)O)(=O)O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 15
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- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 10
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- 239000002131 composite material Substances 0.000 claims description 4
- DDXLVDQZPFLQMZ-UHFFFAOYSA-M dodecyl(trimethyl)azanium;chloride Chemical compound [Cl-].CCCCCCCCCCCC[N+](C)(C)C DDXLVDQZPFLQMZ-UHFFFAOYSA-M 0.000 claims description 4
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- SZEMGTQCPRNXEG-UHFFFAOYSA-M trimethyl(octadecyl)azanium;bromide Chemical compound [Br-].CCCCCCCCCCCCCCCCCC[N+](C)(C)C SZEMGTQCPRNXEG-UHFFFAOYSA-M 0.000 claims description 3
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- ZQMHJBXHRFJKOT-UHFFFAOYSA-N methyl 2-[(1-methoxy-2-methyl-1-oxopropan-2-yl)diazenyl]-2-methylpropanoate Chemical group COC(=O)C(C)(C)N=NC(C)(C)C(=O)OC ZQMHJBXHRFJKOT-UHFFFAOYSA-N 0.000 description 1
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
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- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
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- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
- C09K8/685—Compositions based on water or polar solvents containing organic compounds containing cross-linking agents
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- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
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- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/887—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
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Abstract
The invention relates to the technical field of hydraulic fracturing of oil and gas wells, in particular to a fracturing fluid for realizing high flow conductivity of artificial fractures and a using method thereof, wherein the fracturing fluid is prepared from the following components in percentage by mass: 0.4 to 0.5 percent of thickening agent, 0.4 to 0.5 percent of wetting reversal agent, 0.2 to 0.4 percent of clay stabilizer, 0.3 to 0.5 percent of cross-linking agent and the balance of water. By the fracturing fluid and the use method thereof, the problems of high construction difficulty and high construction cost in the prior art can be effectively solved.
Description
Technical Field
The invention relates to the technical field of hydraulic fracturing of oil and gas wells, in particular to a fracturing fluid for realizing high flow conductivity of artificial fractures and a using method thereof.
Background
At present, the global exploration and development strength of unconventional oil and gas resources such as compact oil, compact gas, shale gas and the like is increased year by year, and hydraulic fracturing is a main means for developing unconventional oil and gas resource reservoir transformation and yield increase. The main goal of hydraulic fracturing is to fracture a length of artificial fracture in a hydrocarbon reservoir and to carry a certain amount of proppant in the fracturing fluid to prop the fracture into a certain conductivity after the fracturing is completed. Aiming at the problems of low flow conductivity of a proppant filling layer, high backflow rate of the proppant and the like after conventional hydraulic fracturing, the 2010 Schlumberger company firstly provides a high flow conductivity fracturing technology, the technology means that the proppant is not uniformly paved in a fracture any more but is agglomerated into clusters through various modes in the fracturing process, dispersed proppant clusters with different sizes are formed in the fracture to support the fracture, a smooth and stable channel network is formed among the proppant clusters, so that the flow conductivity of the fracture is much higher than that of the fracture subjected to conventional fracturing, and the flow resistance of oil gas is greatly reduced.
The key of the high-flow-guide fracturing technology is to realize that the propping agent is agglomerated and paved in the fracture, and at present, 2 different technical modes are mainly adopted.
The first way is to pump a section of high-concentration sand-carrying liquid containing fiber first and then a section of pure cross-linking liquid during construction, and to add sand repeatedly and alternately in a pulse mode, wherein the fiber added in the sand-carrying liquid mainly plays a role in carrying and fixing sand.
In the prior art, a chinese invention patent document with publication No. CN103821491A and publication date 2014, 05 and 28 is proposed, and the technical scheme disclosed in the patent document is as follows: a sand fracturing process is characterized in that fiber-containing sand-carrying liquid and pure jelly spacer fluid are pumped into cracks of an oil and gas well in an alternate circulation mode, the fiber-containing sand-carrying liquid entering the cracks of the oil and gas well is dispersed by perforation blastholes on a pipe column to form lumps with different shapes, the lump fiber-containing sand-carrying liquid is piled up in the cracks from inside to outside to form sand columns, gaps between adjacent lump fiber-containing sand-carrying liquids in the sand columns are filled with the pure jelly spacer fluid, and the cross sections of the whole sand columns are in the shape of piled stone walls; the sand column supports the cracks in the closing process and the closed cracks, and the pure gel spacer part in the sand column forms a low-resistance high-flow-rate seepage channel of oil gas after gel breaking.
In the prior art, a chinese patent document with publication number CN104727799A and publication date 2015, 06, 24 is proposed, and the technical scheme disclosed by the patent document is as follows: a pulse sand fracturing method for realizing high flow conductivity of a crack belongs to the field of oil field development. The method comprises the following steps of 1, aiming at multi-cluster staged fracturing of a horizontal well of an ultra-low permeability reservoir, judging whether high fracture conductivity can be formed through pulse type sand fracturing or not through researching the characteristics of the ultra-low permeability reservoir, and if so, executing step 2; and 2, consolidating sand by fiber fracturing fluid through a pulse type sand adding process in the fracturing process, and forming a column support in the artificial fracture, so that a channel network with high-speed flow conductivity is formed in the artificial fracture, and the artificial fracture has high flow conductivity.
In the actual use process, the following problems can occur in the technical scheme:
(1) Sand plugging risks can be caused by too high sand concentration in the sand carrying liquid;
(2) An additional sand mixing vehicle is needed in construction, sand needs to be added and stopped repeatedly, operation is complex, and construction difficulty is high;
(3) The added fiber can bring certain damage to the reservoir.
The second mode is a proppant self-aggregation treatment technology firstly proposed by Halliburton company, the proppant is subjected to film coating modification before fracturing, proppant particles can be spontaneously aggregated and exist in a sand ball form in the pumping process of fracturing fluid, and a dispersed sand column supporting state is formed after fracture closure, so that high-flow-guide fracturing is realized. Although the method is relatively convenient and fast in construction, the method has the following defects:
(1) During construction, the propping agent needs to be subjected to film coating modification treatment in advance, so that the construction flow is increased;
(2) The coating modification treatment causes the construction cost to be greatly increased.
Disclosure of Invention
The fracturing fluid can lead the added propping agent particles to be aggregated into propping agent groups with different sizes to be dispersed in the fracturing fluid, the propping agent groups are safely and efficiently carried into the stratum by the fracturing fluid to effectively prop the fractures, and smooth and stable channel networks are formed among the propping agent groups, so that the high flow conductivity of the fractures is realized, the oil gas yield is finally improved, and the fracturing fluid has the advantages of simple construction, low risk, low damage and low cost.
The invention is realized by adopting the following technical scheme:
the utility model provides a realize fracturing fluid of high conductivity of artificial fracture which characterized in that: the paint is prepared from the following components in percentage by mass: 0.4 to 0.5 percent of thickening agent, 0.4 to 0.5 percent of wetting reversal agent, 0.2 to 0.4 percent of clay stabilizer, 0.3 to 0.5 percent of cross-linking agent and the balance of water.
The thickening agent is a binary copolymer with ultrahigh molecular weight, and the molecular weight of the thickening agent is 1800-2000 ten thousand.
The thickening agent is prepared by an inverse emulsion polymerization method and comprises an initiator, a monomer for preparing a water phase and an emulsifier for preparing an oil phase; the total concentration of the monomers is 27%, the initiator accounts for 1.5% of the mass percent of the monomers, and the emulsifier accounts for 7% of the mass percent of the oil phase.
The monomer comprises vinyl pyrrolidone and acrylamide, wherein the mass ratio of the vinyl pyrrolidone to the acrylamide is 1.
The emulsifier is a composite emulsifier consisting of OP-10 and Span80, wherein the mass ratio of OP-10 to Span80 is 3.
The preparation method of the thickening agent comprises the following steps: dissolving a monomer in deionized water to prepare a water phase, mixing an emulsifier and solvent oil to prepare an oil phase, and controlling the volume ratio of the oil phase to the water phase to be 1.4:1, mixing the water phase and the oil phase, finally adding an initiator, and reacting for 3.5 hours at the temperature of 45 ℃.
The wetting reversal agent is a cationic quaternary ammonium salt surfactant solution, specifically a 25% dodecyl trimethyl ammonium chloride solution or a 20% octadecyl trimethyl ammonium bromide solution.
The clay stabilizer is a compound solution of a small cation clay stabilizer and inorganic salt, and is specifically prepared by dissolving 35% by mass of trimethyl allyl ammonium chloride, 10% by mass of ammonium chloride and water.
The cross-linking agent comprises the following components in a volume ratio of 4-10: 1, wherein the solution A is an aluminum sulfate solution with the mass fraction of 20%, and the solution B is a citric acid solution with the mass fraction of 50%.
A use method of a fracturing fluid for realizing high flow conductivity of an artificial fracture is characterized by comprising the following steps: sequentially adding water, a thickening agent, a wetting reversal agent and a clay stabilizer into a mixing truck, stirring and mixing uniformly to prepare a fracturing fluid base fluid, and storing the fracturing fluid base fluid in a base fluid tank for later use; adding the solution A and the solution B in the cross-linking agent into a cross-linking agent tank according to a ratio, and uniformly stirring to prepare the cross-linking agent for later use; after fracturing is started, simultaneously adding a fracturing fluid base fluid, a crosslinking agent and a propping agent into a stirring pool of a sand mixing truck, and stirring and crosslinking to form a mixed solution of fracturing fluid jelly and the propping agent, wherein the fracturing fluid jelly carries the propping agent and enters a shaft through a pump truck until the propping agent is in a reservoir fracture; after construction, the fracturing fluid gel is broken and discharged to the ground, and the propping agent is left in the reservoir to support the fractures.
Compared with the prior art, the invention has the beneficial effects that:
1. the molecular chain of the thickening agent contains a large number of strong polar groups, so that solid particles in water can be strongly adsorbed; and the thickening agent is an ultra-high molecular weight polymer, and the ultra-long molecular chain ensures that the thickening agent has stronger trapping and bridging effects on solid particles in water. The characteristics of the thickening agent enable the fracturing fluid to easily agglomerate the proppant particles dispersed in the fracturing fluid.
The wetting reversal agent in the present invention can adsorb on the surface of the proppant and change the proppant from neutral or hydrophilic to hydrophobic, which increases the van der waals force between the proppants, macroscopically manifested as increased viscosity between the proppants, attraction to each other, which promotes easier aggregation of the proppants in the fracturing fluid.
In the invention, the cross-linking agent can enable the fracturing fluid to be quickly cross-linked to form a stable reticular jelly structure, so that the propping agent clusters formed in the fracturing fluid at the early stage are not dispersed under the action of long-time high-speed turbulence of the fracturing fluid; and the crosslinking time of the fracturing fluid can be adjusted by adjusting the proportion of the solution A and the solution B in the crosslinking agent, so that the crosslinking time of the crosslinking agent is 10-60 s, and different construction requirements can be met. The solution A and the solution B can be independently packaged, so that the solutions can be mixed in proportion according to field requirements, and the crosslinking time of the fracturing fluid can be better controlled.
Through the synergistic effect of the thickening agent, the wetting reversion agent and the crosslinking agent, the fracturing fluid gel formed after the fracturing fluid is crosslinked has high viscosity and good temperature resistance and shear resistance, and the proppant particles added into the gel can be aggregated into proppant groups with different sizes to be dispersed in the fracturing fluid, so that the requirements of suspending and carrying the proppant groups into stratum fractures can be met, and the dangerous conditions such as sand removal, sand blocking and the like are not easy to occur. More specifically, the proppant clusters are carried into the stratum safely and efficiently by fracturing fluid jelly, so that the fractures can be effectively supported, and smooth and stable channel networks are formed among the proppant clusters, so that the high flow conductivity of the fractures is realized, and the oil gas yield is finally improved.
2. Compared with the commonly used fiber and pulse type sand adding construction mode, the invention has the following advantages: the fracturing fluid can complete construction under medium and low sand concentration, and the sand blocking risk is low; the proppant can be gathered and high-flow-guide cracks can be formed under the condition of continuous sand adding, and the construction is completely carried out in a conventional fracturing construction mode without additionally increasing construction equipment and operation flow, so that the construction is simpler and more convenient; and a fiber material is not required to be added, so that the reservoir damage caused by the fiber material is avoided.
3. Compared with the construction mode of proppant film-coating modification treatment, the invention can effectively reduce the construction cost.
4. By the use method, after construction is finished, the fracturing fluid jelly can be completely broken and hydrated to be discharged back to the ground, the propping agent clusters are left in the stratum to form efficient support for the cracks, a smooth and stable channel network is formed among the propping agent clusters, and finally high flow conductivity in the cracks is realized. In the process of flowing back of the fracturing fluid, the proppant can still keep the hydrophobic characteristic for a long time and is gathered together, and is not easy to be dispersed by fluid, so that the reflux rate of the proppant is greatly reduced, and the fracturing modification effect is further consolidated.
Drawings
The invention will be described in further detail with reference to the following description taken in conjunction with the accompanying drawings and detailed description, in which:
FIG. 1 is a schematic diagram showing the test results of the temperature and shear resistance test of the fracturing fluid gel prepared in example 2 of the present invention;
fig. 2 is a schematic diagram of a test result of a temperature resistance and shear resistance test of the fracturing fluid gel prepared in example 3 of the present invention.
Detailed Description
Example 1
The invention discloses a fracturing fluid for realizing high flow conductivity of an artificial fracture, which consists of the following components in percentage by mass: 0.5% of thickening agent, 0.45% of wetting reversal agent, 0.2% of clay stabilizer, 0.3% of cross-linking agent and the balance of water.
Wherein the thickening agent is an ultrahigh molecular weight binary copolymer, and the molecular weight of the thickening agent is 1800-2000 ten thousand. The thickening agent is prepared by an inverse emulsion polymerization method, and the preparation dosage and the reaction conditions are as follows:
the monomer is two polar substances of vinyl pyrrolidone and acrylamide, and the use ratio is that the vinyl pyrrolidone: acrylamide =1, total monomer concentration 27%.
The initiator is dimethyl azodiisobutyrate, and the dosage of the initiator is 1.5 percent of the mass percent of the monomers.
The emulsifier is a composite emulsifier consisting of OP-10 and Span80, the dosage of the composite emulsifier accounts for 7 percent of the mass percent of the oil phase, and the content ratio is OP-10: span80= 3; wherein the oil phase is prepared by mixing emulsifier and solvent oil.
Dissolving a monomer in deionized water to prepare a water phase, mixing an emulsifier and solvent oil to prepare an oil phase, and controlling the volume ratio of the oil phase to the water phase to be 1.4:1, mixing the water phase and the oil phase, finally adding an initiator, and reacting for 3.5 hours at the temperature of 45 ℃.
The wetting reversion agent is dodecyl trimethyl ammonium chloride solution with the mass fraction of 25%. The clay stabilizer is prepared by dissolving 35% of trimethyl allyl ammonium chloride by mass fraction, 10% of ammonium chloride by mass fraction and water. The cross-linking agent comprises a solution A and a solution B. Wherein the solution A is an aluminum sulfate solution with the mass fraction of 20%, the solution B is a citric acid solution with the mass fraction of 50%, and the volume ratio of the two solutions is that of the solution A: solution B =4:1. and the solution A and the solution B are independently packaged and are uniformly mixed in proportion to obtain the cross-linking agent before construction.
The preparation method of the fracturing fluid comprises the following steps:
S 1 preparing base liquid and preparing a cross-linking agent;
preparing a base liquid: 494.25g of water is added into a stirrer, the rotating speed of the stirrer is adjusted to 1500r/min, 2.5g of thickening agent, 2.25g of wetting reversal agent and 1g of clay stabilizer are sequentially added into the water and continuously stirred for 5min to prepare base liquid which is put into a beaker for standby.
Preparing a cross-linking agent: 4ml of the solution A and 1ml of the solution B are added into a beaker and stirred evenly to prepare the cross-linking agent for standby.
S 2 Preparing a fracturing fluid gel: pouring 400ml of base liquid into a stirrer, and adjusting the rotating speed of the stirrer to enable the liquid level to form a vortex until the vortex formed by the liquid can see the top end of a middle shaft of a paddle blade of the stirrer, so that the stirrer rotates at a constant speed; then 1.2ml of cross-linking agent is added until the vortex disappears, thus preparing the fracturing fluid gel.
In the fracturing construction, the use method of the fracturing fluid is as follows: firstly, sequentially adding water, a thickening agent, a wetting reversal agent and a clay stabilizer into a mixing truck according to a proportion, stirring and mixing uniformly, preparing a base fluid, and storing the base fluid in a base fluid tank for later use; then adding the solution A and the solution B of the cross-linking agent into a cross-linking agent tank according to a certain proportion and uniformly stirring to prepare the cross-linking agent for later use; after fracturing is started, simultaneously adding the base fluid, the cross-linking agent and the propping agent into a stirring pool of a sand mixing truck, and stirring and cross-linking to form a mixed solution of fracturing fluid jelly and the propping agent, wherein the fracturing fluid jelly carries with the propping agent and enters a shaft through a pump truck until the propping agent reaches a reservoir fracture; after construction, the fracturing fluid gel is broken and discharged to the ground, and the propping agent is left in the reservoir to support the fractures.
The apparent viscosity of the base fluid, the crosslinking time of the fracturing fluid and the gel breaking performance are tested, and the method specifically comprises the following steps:
and (3) testing the apparent viscosity of the base fluid: taking 350mL of the base solution prepared in the step, placing the base solution into a constant-temperature water bath at the temperature of 30 ℃, keeping the temperature for 4 hours, and measuring the rotating speed of 100r/min and the shearing rate of 170s by using a six-speed rotary viscometer -1 Viscosity of the base fluid. The viscosity of the fracturing fluid base fluid is measured to be 48mPa.
And (3) testing the crosslinking time of the fracturing fluid: according to the method for preparing the fracturing fluid gel, a stopwatch is used for recording the time from adding the crosslinking agent into the stirrer until the vortex disappears and the liquid surface is slightly protruded, namely the crosslinking time. The crosslinking time of the present fracturing fluid was measured to be 59 seconds.
And (3) gel breaking performance test: and taking 300mL of the base fluid prepared in the step, adding 3mL of the prepared APS gel breaker solution with the mass fraction of 1% by using a pipette, uniformly stirring, adding 1.5mL of a cross-linking agent according to the method for preparing the fracturing fluid gel to prepare the fracturing fluid gel, putting the fracturing fluid gel into a closed container, putting the container into an electric thermostat, heating to the constant temperature of 85 ℃, and breaking the fracturing fluid for 4 hours to prepare the gel breaking solution. And (3) placing the gel breaking solution into a constant-temperature water bath at 30 ℃ for constant temperature for 4 hours, and testing the viscosity of the gel breaking solution by using a product capillary viscometer. The measured viscosity of the gel breaking liquid of the fracturing fluid is 3.125mPa.s, which shows that the fracturing fluid has good gel breaking performance.
Example 2
The invention discloses a fracturing fluid for realizing high flow conductivity of an artificial fracture, which consists of the following substances in percentage by mass: 0.45% of thickening agent, 0.4% of wetting reversal agent, 0.3% of clay stabilizer, 0.4% of cross-linking agent and the balance of water.
The proportion of the thickener and the preparation method thereof are the same as those in example 1, and are not described herein again.
The wetting reversal agent is an octadecyl trimethyl ammonium bromide solution with the mass fraction of 20%. The clay stabilizer is prepared by dissolving 35% of trimethyl allyl ammonium chloride by mass fraction, 10% of ammonium chloride by mass fraction and water. The cross-linking agent comprises a solution A and a solution B, wherein the solution A is an aluminum sulfate solution with the mass fraction of 20%, the solution B is a citric acid solution with the mass fraction of 50%, and the using volume ratio of the two solutions is that the solution A: solution B =6:1.
the preparation method of the fracturing fluid comprises the following steps:
S 1 preparing base liquid and preparing a cross-linking agent;
preparing a base liquid: 494.25g of water is added into a stirrer, the rotating speed of the stirrer is adjusted to 1500r/min, 2.25g of thickening agent, 2g of wetting reversal agent and 1.5g of clay stabilizer are sequentially added into the water and continuously stirred for 5min to prepare base liquid which is put into a beaker for standby.
Preparing a cross-linking agent: 6ml of the solution A and 1ml of the solution B are added into a beaker and stirred uniformly to prepare the cross-linking agent for standby.
S 2 Preparing a fracturing fluid gel: 400ml of base liquid is poured intoIn the stirrer, the rotating speed of the stirrer is adjusted to enable the liquid level to form a vortex until the vortex formed by the liquid can see the top end of the central shaft of the blade of the stirrer, so that the stirrer rotates at a constant speed; then 1.6ml of cross-linking agent is added until the vortex disappears, thus preparing the fracturing fluid gel.
The use method of the fracturing fluid is the same as that of the embodiment 1, and the description is omitted here.
The apparent viscosity of the base fluid, the crosslinking time of the fracturing fluid, the temperature resistance, the shear resistance and the flow conductivity are tested, and the method specifically comprises the following steps:
and (3) testing the apparent viscosity of the base fluid: the apparent viscosity of the base fluid of the fracturing fluid is 42mPa.s by using the method for testing the apparent viscosity of the base fluid in the example 1.
And (3) testing the crosslinking time of the fracturing fluid: the crosslinking time of the fracturing fluid measured by the method for testing the crosslinking time of the fracturing fluid in example 1 is 44s.
Testing the temperature resistance and the shearing resistance: taking the prepared fracturing fluid jelly, filling the fracturing fluid into a viscometer sample cup by using a high-temperature high-pressure coaxial cylinder rotational viscometer, heating the sample, and simultaneously heating a rotor at a shear rate of 170 -1 Rotating, keeping the shearing rate and the temperature unchanged after the temperature reaches 80 ℃ until the shearing time reaches 90 min. The test result is shown in the attached figure 1 of the specification, and the fracturing fluid has excellent temperature resistance and shear resistance.
And (3) testing the flow conductivity: according to a method in an industry standard ' evaluation recommendation method for short-term conductivity of fracturing proppant filling layer ' (SY/T6302-2009 '), the fracturing fluid disclosed by the invention is subjected to sand carrying, sand paving in a conductivity chamber, gel breaking in the conductivity chamber and conductivity testing of the conductivity chamber, and is compared with the conductivity generated by a conventional fracturing fluid. The experimental conditions were as follows: the experimental temperature is 85 ℃, the proppant is 20/40 mesh ceramic aggregate, and the sand laying concentration is 10kg/m 2 The fluid viscosity was 1.0 mPas, and the fluid density was 1.0kg/cm 3 The closing pressure was 50MPa. The experimental results obtained: the flow conductivity of a simulated crack generated by the fracturing fluid is 85.3 mu m 2 Cm; the flow conductivity of a simulated fracture generated by the conventional fracturing fluid is 49.7 mu m 2 Cm. Is formed by experimentThe flow conductivity of the simulated fracture generated by the method is 72% higher than that of the conventional fracturing fluid, and higher flow conductivity can be realized.
Example 3
The invention discloses a fracturing fluid for realizing high flow conductivity of an artificial fracture, which consists of the following substances in percentage by mass: 0.4% of thickening agent, 0.5% of wetting reversal agent, 0.4% of clay stabilizer, 0.5% of cross-linking agent and the balance of water.
The proportion of the thickener and the preparation method thereof are the same as those in example 1, and are not described herein again.
The wetting reversal agent is a 25% dodecyl trimethyl ammonium chloride solution by mass fraction. The clay stabilizer is prepared by dissolving 35% of trimethyl allyl ammonium chloride by mass fraction, 10% of ammonium chloride by mass fraction and water. The cross-linking agent comprises a solution A and a solution B, wherein the solution A is an aluminum sulfate solution with the mass fraction of 20%, the solution B is a citric acid solution with the mass fraction of 50%, and the using volume ratio of the two solutions is that the solution A: solution B =10:1.
the preparation method of the fracturing fluid comprises the following steps:
S 1 preparing base liquid and preparing a cross-linking agent;
preparing a base liquid: 493.5g of water is added into a stirrer, the rotating speed of the stirrer is adjusted to be 1500r/min, 2g of thickening agent, 2.5g of wetting reversal agent and 2g of clay stabilizer are sequentially added into the water, and the mixture is continuously stirred for 5min to prepare base liquid which is put into a beaker for standby.
Preparing a cross-linking agent: 10ml of the cross-linking agent A solution and 1ml of the cross-linking agent B solution are added into a beaker and evenly stirred to prepare the cross-linking agent for standby.
S 2 Preparing a fracturing fluid gel: pouring 400ml of base liquid into a stirrer, and adjusting the rotating speed of the stirrer to enable the liquid level to form a vortex until the vortex formed by the liquid can see the top end of a middle shaft of a paddle blade of the stirrer, so that the stirrer rotates at a constant speed; then 2ml of cross-linking agent is added until the vortex disappears, and then the fracturing fluid gel is prepared.
The apparent viscosity of the base fluid, the crosslinking time of the fracturing fluid, the temperature resistance, the shear resistance and the flow conductivity are tested, and the method specifically comprises the following steps:
and (3) testing the apparent viscosity of the base fluid: the base fluid viscosity of the fracturing fluid measured by the method for measuring the apparent viscosity of the base fluid in example 1 is 40mpa.s.
And (3) testing the crosslinking time of the fracturing fluid: the crosslinking time of the fracturing fluid measured by the method for testing the crosslinking time of the fracturing fluid in example 1 is 10s.
Testing the temperature resistance and the shearing resistance: by using the temperature and shear resistance test method in the embodiment 2, the test results are shown in the attached figure 2 of the specification, and the results show that the fracturing fluid has excellent temperature and shear resistance.
And (3) testing the flow conductivity: according to a method in an industry standard ' evaluation recommendation method for short-term conductivity of fracturing proppant filling layer ' (SY/T6302-2009 '), the fracturing fluid disclosed by the invention is subjected to sand carrying, sand paving in a conductivity chamber, gel breaking in the conductivity chamber and conductivity testing of the conductivity chamber, and is compared with the conductivity generated by a conventional fracturing fluid. The experimental conditions were as follows: the experimental temperature is 85 ℃, the type of the propping agent is 20/40 mesh quartz sand, and the sand laying concentration is 15kg/m 2 The fluid viscosity was 1.0 mPas and the fluid density was 1.0kg/cm 3 The closing pressure was 30MPa. The experimental results obtained were: the flow conductivity of the simulated fracture generated by the fracturing fluid is 138.2 mu m 2 Cm; the flow conductivity of a simulated fracture generated by the conventional fracturing fluid is 64.8 mu m 2 Cm. The experimental result shows that the flow conductivity of the simulated fracture is 113.3% higher than that of the conventional fracturing fluid, and higher flow conductivity can be realized.
In summary, after reading the present disclosure, those skilled in the art should make various other modifications without creative efforts according to the technical solutions and concepts of the present disclosure, which are within the protection scope of the present disclosure.
Claims (10)
1. The utility model provides a realize high conductivity's of artificial fracture fracturing fluid which characterized in that: the paint is prepared from the following components in percentage by mass: 0.4 to 0.5 percent of thickening agent, 0.4 to 0.5 percent of wetting reversal agent, 0.2 to 0.4 percent of clay stabilizer, 0.3 to 0.5 percent of cross-linking agent and the balance of water.
2. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 1, wherein: the thickening agent is a binary copolymer with ultrahigh molecular weight, and the molecular weight of the thickening agent is 1800-2000 ten thousand.
3. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 2, wherein: the thickening agent is prepared by an inverse emulsion polymerization method and comprises an initiator, a monomer for preparing a water phase and an emulsifier for preparing an oil phase; the total concentration of the monomers is 27%, the initiator accounts for 1.5% of the mass percent of the monomers, and the emulsifier accounts for 7% of the mass percent of the oil phase.
4. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 3, wherein: the monomer is vinyl pyrrolidone and acrylamide, wherein the mass ratio of the vinyl pyrrolidone to the acrylamide is 1.
5. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 3, wherein: the emulsifier is a composite emulsifier consisting of OP-10 and Span80, wherein the mass ratio of OP-10 to Span80 is 3.
6. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 4 or 5, wherein: the preparation method of the thickening agent comprises the following steps: dissolving a monomer in deionized water to prepare a water phase, mixing an emulsifier and solvent oil to prepare an oil phase, and controlling the volume ratio of the oil phase to the water phase to be 1.4:1, mixing the water phase and the oil phase, finally adding an initiator, and reacting for 3.5 hours at the temperature of 45 ℃.
7. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 1, wherein: the wetting reversal agent is a cationic quaternary ammonium salt surfactant solution, specifically a 25% dodecyl trimethyl ammonium chloride solution or a 20% octadecyl trimethyl ammonium bromide solution.
8. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 1, wherein: the clay stabilizer is a compound solution of a small cation clay stabilizer and inorganic salt, and is specifically prepared by dissolving 35 mass percent of trimethyl allyl ammonium chloride, 10 mass percent of ammonium chloride and water.
9. The fracturing fluid for realizing high conductivity of artificial fractures according to claim 1, wherein: the cross-linking agent comprises the following components in a volume ratio of 4-10: 1, wherein the solution A is an aluminum sulfate solution with the mass fraction of 20%, and the solution B is a citric acid solution with the mass fraction of 50%.
10. A use method of a fracturing fluid for realizing high flow conductivity of an artificial fracture is characterized by comprising the following steps: sequentially adding water, a thickening agent, a wetting reversal agent and a clay stabilizer into a mixing truck, stirring and mixing uniformly to prepare a fracturing fluid base fluid, and storing the fracturing fluid base fluid in a base fluid tank for later use; adding the solution A and the solution B in the cross-linking agent into a cross-linking agent tank according to a ratio, and uniformly stirring to prepare the cross-linking agent for later use; after fracturing is started, simultaneously adding a fracturing fluid base fluid, a crosslinking agent and a propping agent into a stirring pool of a sand mixing truck, and stirring and crosslinking to form a mixed solution of fracturing fluid jelly and the propping agent, wherein the fracturing fluid jelly carries the propping agent and enters a shaft through a pump truck until the propping agent is in a reservoir fracture; after the construction is finished, the gel of the fracturing fluid gel is broken and discharged back to the ground, and the propping agent is left in the reservoir to support the fractures.
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