CN112410001A - Floating agent and high-strength floating agent partition plate process for controlling fracture cross-layer propagation - Google Patents
Floating agent and high-strength floating agent partition plate process for controlling fracture cross-layer propagation Download PDFInfo
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- 238000007667 floating Methods 0.000 title claims abstract description 147
- 238000000034 method Methods 0.000 title claims abstract description 29
- 230000008569 process Effects 0.000 title claims abstract description 23
- 238000005192 partition Methods 0.000 title claims description 26
- 239000003795 chemical substances by application Substances 0.000 claims description 90
- 239000011324 bead Substances 0.000 claims description 42
- 239000002245 particle Substances 0.000 claims description 41
- 239000007788 liquid Substances 0.000 claims description 31
- 239000004576 sand Substances 0.000 claims description 22
- 239000012530 fluid Substances 0.000 claims description 19
- 239000006228 supernatant Substances 0.000 claims description 14
- 238000002347 injection Methods 0.000 claims description 5
- 239000007924 injection Substances 0.000 claims description 5
- 239000000203 mixture Substances 0.000 claims description 3
- 230000000694 effects Effects 0.000 abstract description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 22
- 238000005086 pumping Methods 0.000 description 10
- 238000010586 diagram Methods 0.000 description 8
- 239000010410 layer Substances 0.000 description 8
- 239000000463 material Substances 0.000 description 8
- 238000009826 distribution Methods 0.000 description 7
- 238000006073 displacement reaction Methods 0.000 description 6
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- 239000003921 oil Substances 0.000 description 5
- 238000004088 simulation Methods 0.000 description 5
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- 238000013508 migration Methods 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
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- 239000000243 solution Substances 0.000 description 3
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 241001391944 Commicarpus scandens Species 0.000 description 2
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- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000003513 alkali Substances 0.000 description 1
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- TWNQGVIAIRXVLR-UHFFFAOYSA-N oxo(oxoalumanyloxy)alumane Chemical compound O=[Al]O[Al]=O TWNQGVIAIRXVLR-UHFFFAOYSA-N 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 238000003825 pressing Methods 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
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- 239000003079 shale oil Substances 0.000 description 1
- 235000012239 silicon dioxide Nutrition 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- 125000006850 spacer group Chemical group 0.000 description 1
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- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/5045—Compositions based on water or polar solvents containing inorganic compounds
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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
- E21B43/26—Methods for stimulating production by forming crevices or fractures
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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
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E10/00—Energy generation through renewable energy sources
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Abstract
The invention discloses a floating agent for fracturing and a high-strength floating agent clapboard process for controlling fracture cross-layer expansion, and relates to the technical field of oil-gas exploration. Therefore, when the floating agent for fracturing is applied to high-temperature steering fracturing, the floating agent has high temperature resistance, high pressure bearing capacity and good plugging effect.
Description
Technical Field
The invention relates to the technical field of oil and gas exploration, in particular to a floating agent and a high-strength floating agent partition plate process for controlling fracture crossing and spreading.
Background
With the deep exploration and development of oil and gas, the special reservoir stratum is efficiently transformed, and brand new requirements are made on the performance of the temporary plugging agent. Wherein, the floating agent is used as one of temporary plugging agents, and the function of the floating agent is to plug the upper reservoir stratum and prevent the crack from extending upwards. At present, various clean steering materials comprising fibers, pellets and the like are successfully developed in China, a special material adding device or equipment is matched, a process optimization method is preliminarily formed, and the method is successfully applied on site. The main problems of the existing fiber materials are that the pressure bearing capacity is limited, the composite material has higher plugging efficiency and pressure bearing capacity to cracks, the fibers are easy to plug, but the fibers are difficult to transport in a long distance due to the winding limitation, so that the temporary plugging steering near a shaft is easy to realize, and the high temperature resistance is insufficient.
Disclosure of Invention
The invention mainly aims to provide a floating agent for fracturing and a high-strength floating agent clapboard process for controlling the cross-layer expansion of a fracturing fracture, and aims to provide the floating agent for fracturing.
In order to achieve the purpose, the invention provides a floating agent for fracturing, which comprises floating beads.
Optionally, the particle size of the floating beads is 20-200 meshes.
Optionally, the floating beads comprise a mixture of floating beads with a particle size of 20-40 meshes, floating beads with a particle size of 100-120 meshes and floating beads with a particle size of 180-200 meshes, wherein the mass ratio of the floating beads with a particle size of 20-40 meshes, the floating beads with a particle size of 100-120 meshes and the floating beads with a particle size of 180-200 meshes is 1: 2: 5.2.
the invention further provides a high-strength floating agent partition plate process for controlling the cross-layer expansion of a fracturing fracture, which comprises the following steps:
s10, uniformly mixing the floating agent for fracturing with the sand carrying liquid to form a floating liquid, wherein the floating agent for fracturing is the floating agent for fracturing;
and S20, injecting the supernatant into a fracturing fracture of the high-temperature reservoir, and enabling the supernatant to form a first partition plate on the upper part of the fracturing fracture so as to enable the fracturing fracture to extend downwards.
Optionally, in step S10, the sand-carrying fluid is slick water.
Optionally, in step S10, the slickwater has a viscosity of 1-10 mPa · S.
Optionally, in step S10, the supernatant has a sand ratio of 5% to 6%.
Optionally, in step S20, the injection flow rate of the supernatant is 3-5 m3/min。
Optionally, in step S20, the forming time of the first partition board is at least 20 min.
Optionally, the thickness of the first separator is 5.2-17.5 cm.
In the technical scheme provided by the invention, the floating agent for fracturing comprises floating beads, wherein the chemical components of the floating beads mainly comprise silicon dioxide and aluminum oxide, the floating beads are a tiny hollow spherical powder substance which is formed by melting the surface of a product, sealing air holes and having a honeycomb structure in the interior by accurately controlling the temperature and the material stagnation time under the high-temperature condition of more than 1500 ℃ as special raw materials, and the floating beads are in a microspherical appearance, are insoluble in acid-base oil saline water, can resist temperature of 1600-1700 ℃, have good dispersibility and fluidity and compressive strength of 20MPa, are generally not easy to break in fracturing, can ensure the strength of a formed partition plate, and partially break and flow out along with liquid due to the fracture closing pressure in the post-fracturing production, so that partial blockage is removed, and the permeability is recovered. Therefore, when the floating agent for fracturing is applied to high-temperature steering fracturing, the floating agent has high temperature resistance, high pressure bearing capacity and good plugging effect.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other related drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a microscope view of floating beads in the floating agent for fracturing provided by the invention;
FIG. 2 is a cross-sectional view showing the state of propagation of a fracture when the fracturing floating agent of the present invention is used to block the fracture;
FIG. 3 is a schematic flow diagram of one embodiment of a high strength buoyant agent spacer process for controlling fracture cross-bed propagation in accordance with the present invention;
FIG. 4 is a distribution form diagram of the floating agent for fracturing under different viscosity of the sand-carrying fluid in FIG. 3;
fig. 5 is a distribution pattern diagram of the floating agent for fracturing under different sand ratios in fig. 3.
The implementation, functional features and advantages of the objects of the present invention will be further explained with reference to the accompanying drawings.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below. The examples, in which specific conditions are not specified, were conducted under conventional conditions or conditions recommended by the manufacturer. The reagents or instruments used are not indicated by the manufacturer, and are all conventional products available commercially.
With the deep exploration and development of oil and gas, the special reservoir stratum is efficiently transformed, and brand new requirements are made on the performance of the temporary plugging agent. Wherein, the floating agent is used as one of temporary plugging agents and has the function of plugging an upper reservoir stratum to prevent a crack from extending upwards. At present, various clean steering materials comprising fibers, pellets and the like are successfully developed in China, a special material adding device or equipment is matched, a process optimization method is preliminarily formed, and the method is successfully applied on site. The main problems of the existing fiber materials are that the pressure bearing capacity is limited, the composite material has higher plugging efficiency and pressure bearing capacity to cracks, the fibers are easy to plug, but the fibers are difficult to transport in a long distance due to the winding limitation, so that the temporary plugging steering near a shaft is easy to realize, and the high temperature resistance is insufficient.
In view of the above, the invention provides a floating agent for fracturing, and aims to provide a floating agent for fracturing, which has high temperature resistance, high pressure bearing capacity and good plugging effect when applied to high-temperature steering fracturing. FIG. 1 is a microscope view of floating beads in the floating agent for fracturing provided by the invention; FIG. 2 is a sectional view showing the state of propagation of a fracture at the time of plugging the fracture by using the floating agent for fracturing provided by the present invention.
The floating agent for fracturing comprises floating beads, and referring to fig. 1, the floating beads are hollow powder substances which are formed by melting special materials at high temperature and have honeycomb-shaped inner parts and micro-spherical outer parts. The material is grey white in appearance and shows as tiny hollow transparent spheres under a microscope, and the material has a plurality of remarkable advantages as a floating agent for fracturing: (1) insoluble in acid, alkali, oil and brine; (2) the temperature resistance can reach 1600-1700 ℃; (3) excellent floatability, and bulk density of 400-800kg/m3Watch, watchApparent density is 800-3The particle size can be produced according to the requirement; (4) has good dispersibility and fluidity and the compressive strength reaches 20 MPa. The price depends on the mesh number, the smaller the mesh number is, the higher the price is, generally between 5000-; (5) the floating beads are not easy to break in the fracturing, and the strength of the partition plate can be ensured. But in the production after pressing, due to the action of crack closing pressure, part of floating beads can be broken and flow out along with liquid, partial blockage can be removed, and the permeability can be recovered. Therefore, when the floating bead is used as a component of the floating agent, the floating agent can resist high temperature, has high pressure-bearing capacity and has good plugging effect when being applied to high-temperature steering fracturing.
FIG. 2 is a cross-sectional view showing the state of propagation of a fracture during fracture plugging by using the floating agent of the present invention. As can be seen from fig. 2, when the floating agent provided by the present invention is used, the fracture turns to extend toward the height direction of the fracture after the plugging partition is formed, and the fracture height fully extends downward, which indicates that the floating agent provided by the present invention can effectively realize temporary plugging turning fracturing (it should be noted that the temporary plugging agent is further added in this test, and the plugging partition is formed at the front end of the fracture, so the fracture does not extend forward).
The invention optimizes the particle size ratio of floating bead particles, wherein the particle size of the floating beads is preferably 20-200 meshes, and the floating bead particle size is further optimized as follows: the floating beads comprise a mixture of floating beads with the particle size of 20-40 meshes, floating beads with the particle size of 100-120 meshes and floating beads with the particle size of 180-200 meshes, wherein the mass ratio of the floating beads with the particle size of 20-40 meshes, the floating beads with the particle size of 100-120 meshes and the floating beads with the particle size of 180-200 meshes is 1: 2: 5.2. repeated experiments and simulations show that the floating agent has high temperature resistance, high pressure bearing capacity and the best plugging effect when applied to high-temperature steering fracturing under the conditions of the particle size range and the proportion.
In addition, considering that the floating speed is different among different particle sizes, it is preferable that the particles of the above three particle sizes are sufficiently mixed and injected when the floating agent is injected into the fracturing crack in the embodiment of the present invention. Therefore, in the floating process of the floating agent particles, the floating agent particles with different particle diameters are mutually influenced, so that the formed partition plate is more uniform and compact and has high pressure bearing capacity.
The invention further provides a high-strength floating agent partition plate process for controlling the cross-layer expansion of a fracturing fracture, and fig. 3 is a schematic flow diagram of an embodiment of the high-strength floating agent partition plate process for controlling the cross-layer expansion of the fracturing fracture; FIG. 4 is a distribution form diagram of the floating agent under different viscosity of the sand-carrying fluid in FIG. 3; fig. 5 is a distribution form diagram of the floating agent under different sand ratios in fig. 3.
Referring to fig. 3, the high strength floating agent separator process for controlling fracture cross-layer propagation according to the present invention includes the following steps:
s10, uniformly mixing the floating agent for fracturing with the sand carrying liquid to form a floating liquid, wherein the floating agent for fracturing is the floating agent for fracturing.
In this step, preferably, the sand-carrying fluid is slickwater. Slickwater is a fracturing fluid system for hydraulic fracturing of shale oil and gas reservoirs, and is one of key liquids for shale gas development. Compared with the traditional gel fracturing fluid system, the slickwater fracturing fluid system is widely applied to shale gas development by virtue of the characteristics of high efficiency and low cost. In this application with slickwater as the sand-carrying fluid, be favorable to it to pour into the back in the fracturing crack, can not pollute fracturing fluid, increase the compatibility.
Furthermore, the invention uses a CFD-DEM coupling method to carry out the micro-migration numerical simulation of the floating agent, and FIG. 4 is a distribution form diagram of the floating agent under different sand-carrying fluid viscosities (gray particles in FIG. 4 are floating bead particles). As can be seen from fig. 3, as the viscosity of the sand carrier increases, the laying thickness of the floating agent decreases, because as the viscosity of the sand carrier increases, the laying thickness decreases, the laying concentration increases, the sand carrier has higher sand carrying capacity as the viscosity of the sand carrier increases, and the floating capacity of the floating agent is reduced, so that the low-viscosity slick water is preferably used in the present invention. According to the invention, the viscosity of the sand carrying fluid is preferably in the range of 1-10 mPa & s, the floating agent can achieve enough laying thickness in the stratum in the range, but if the conditions allow the viscosity of slickwater to be as low as possible, the laying effect is good, and the cost is low.
In addition, the invention also optimizes the sand ratio of the supernatant fluid, and the sand ratio refers to fracturing constructionThe volume ratio of the sand adding amount (pile volume) to the sand carrying liquid in the process is m3/m3Fig. 5 is a distribution form diagram (gray particles in fig. 5 are floating agent particles) of the floating agent in fig. 3 at different sand ratios, and it can be seen that the thickness of the obtained partition plate is too low when the sand ratio is 2% and 4%, and therefore, in the embodiment of the present invention, the sand ratio of the floating liquid is 5% to 6%.
And S20, injecting the supernatant into a fracturing fracture of the high-temperature reservoir, and enabling the supernatant to form a first partition plate on the upper part of the fracturing fracture so as to enable the fracturing fracture to extend downwards.
In the embodiment of the invention, after the floating agent is injected into the fracturing crack, the temporary plugging agent is also injected to plug the front end of the fracturing crack so as to form a second partition plate at the front end of the fracturing crack and inhibit the horizontal expansion of the fracturing crack.
According to the embodiment of the invention, a large-scale visual particle migration simulation device is used for carrying out an object model experiment, and a CFD-DEM is matched for carrying out the micro migration numerical simulation of the floating agent, so that the discharge capacity during fracturing construction is optimized finally. When the discharge capacity is small, the flowing speed of liquid in the pipeline is low, the floating agent is difficult to enter from the liquid mixing tank and quickly floats in the pipeline, and the floating agent cannot enter cracks easily. When the flow velocity is too large, the high flow velocity can increase the dragging force of the migration of the floating agent due to the unchanged concentration of the sand, and the floating agent is basically carried into the crack. Therefore, the injection flow of the upper floating liquid is preferably 3-5 m3Min (linear flow rate about 0.3-0.5m/s)
In addition, the invention carries out the highest plugging pressure test under different first partition plate thickness conditions, and the result is shown in the following table 1, the effective plugging pressure gradually increases with the increase of the first partition plate thickness, but the effective plugging pressure y has a nonlinear relationship, and after the data are fitted, the relational expression between the first partition plate thickness x and the effective plugging pressure y is: y is 0.1005x2–1.2295x+4.4436。
Table 1 effective plugging pressure test results for different first separator plate thicknesses
In the actual operation process, relevant process parameters can be set according to actual requirements by taking the table 1 and the relational expression as references. For example, for an effective plugging pressure of 10MPa, the present invention suggests that the first separator thickness is not less than 16 cm. According to the application scene of the invention, the thickness of the first separator is 5.2-17.5 cm.
In addition, in the embodiment of the present invention, the pump stopping process is adopted during the injection of the supernatant, i.e. the pump is stopped for a period of time after the supernatant is injected, the first partition is formed by the floating of the particles in the floating agent, such as floating beads, and the pump stopping time is related to the floating speed of the particles in the floating agent, such as floating beads.
TABLE 2 Floating velocity of floating agent with different particle size
According to the above table, taking the perforation position 2m away from the storage barrier boundary as an example, the first partition can be formed by stopping the pump for 20min, and in summary, in the embodiment of the present invention, the forming time of the first partition is at least 20 min.
The method establishes a single seam with a half seam length of 120m and certain laying concentration in Meyer software, wherein the thickness of a reservoir is 100m, the thickness of an upper interlayer of the reservoir is 20m, and the thickness of a lower interlayer is 20 m; the permeability is 0.1md, and the supernatant density is 0.75g/cm3Total liquid amount of 200m3The floating agent accounts for about 4000kg of the total liquid mass and accounts for 2 percent. The invention optimizes the liquid volume distribution, pumping rate, viscosity of sand carrying liquid and particle size of floating agent in stages for perforation thicknesses of 20m, 50m and 80m respectively. The test results were as follows:
(1) in order to realize uniform and good laying of floating agent with the perforation thickness of 20m, the pumping speed of a front pump is recommended to be 0.5m3Permin, the pumping speed of the floating liquid is 3m3Permin, displacement fluid pumping rate 4m3Min; front liquid 10m3And upward floating liquid 20m3180m of displacement fluid3The viscosity of the sand-carrying liquid is selected to be within 1-10 mPa.s, the particle size of the floating agent is 30-50 meshes, and the density of the floating liquid is 0.75g/cm3。
(2) In order to realize uniform and good laying of floating agent with the perforation thickness of 50m, the pumping speed of a front pump is recommended to be 0.5m3Permin, the pumping speed of the floating liquid is 4m3Min, displacement liquid pumping speed 5m3Min; front liquid 25m3Supernatant 50m3425m of displacement fluid3。
(3) In order to realize uniform and good laying of floating agent with the perforation thickness of 80m, the pre-pump is recommended to have the pumping speed of 2m3Permin, upper floating liquid pumping speed 7m3Min, displacement liquid pumping speed 5m3Min; pad liquid 40m380m of supernatant fluid3680m of displacement fluid3。
The floating agent selected by the invention aims at the difficulty of site construction, and is particularly suitable for a site reservoir, and has the characteristics that the floating agent is positioned at 5000m underground, the temperature of the reservoir reaches 160 ℃, and the thickness of the reservoir reaches 100 m. Aiming at the reservoir, in order to increase the probability of communicating rich gas and oil fracture holes and complete safe and efficient transformation, the invention provides optimization of the process parameters of large-amplitude expansion of the lower fracture height. The fracturing crack expansion numerical simulation of the FRACMAN floating agent shows that in the pre-liquid crack making stage, the floating agent needs to be pumped in time, the crack can immediately penetrate through a layer and expand after crossing a floating partition plate, and the second-stage plugging needs to be carried out before the crack is subjected to the layer-crossing expansion; in total, two times of plugging are needed, the first time is up to 27m, the second time is up to 46m, after the second plugging, the crack can not flow up to the penetrating layer any more, even if the discharge capacity is increased to 12m3And/min. Based on the research results, the invention designs a crack form construction scheme with a target half-crack length of 100m and a crack height of about 20m, and the specific design of the floating agent plugging fracturing pump injection program is shown in table 3.
TABLE 3 proppant plugging fracturing pump injection procedure
The above is only a preferred embodiment of the present invention, and it is not intended to limit the scope of the invention, and various modifications and changes will occur to those skilled in the art. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention shall be included in the scope of the present invention.
Claims (10)
1. The floating agent for fracturing is characterized by comprising floating beads.
2. The floating agent for fracturing as claimed in claim 1, wherein said floating bead has a particle size of 20 to 200 mesh.
3. The floating agent for fracturing as claimed in claim 2, wherein the floating beads comprise a mixture of floating beads with a particle size of 20 to 40 mesh, floating beads with a particle size of 100 to 120 mesh and floating beads with a particle size of 180 to 200 mesh, wherein the mass ratio of the floating beads with a particle size of 20 to 40 mesh, the floating beads with a particle size of 100 to 120 mesh and the floating beads with a particle size of 180 to 200 mesh is 1: 2: 5.2.
4. a high-strength floating agent partition plate process for controlling fracture cross-layer propagation is characterized by comprising the following steps:
s10, uniformly mixing a floating agent for fracturing with a sand carrying liquid to form a floating liquid, wherein the floating agent for fracturing is the floating agent for fracturing according to any one of claims 1 to 3;
and S20, injecting the supernatant into a fracturing fracture of the high-temperature reservoir, and enabling the supernatant to form a first partition plate on the upper part of the fracturing fracture so as to enable the fracturing fracture to extend downwards.
5. The high strength proppant separator process for controlling the cross-bed propagation of a fracture as set forth in claim 4, wherein the sand-carrying fluid is slickwater in step S10.
6. The high-strength buoyant agent separator process for controlling the fracture strike-through propagation of claim 5, wherein in step S10, the slickwater has a viscosity of 1-10 mPa-S.
7. The high strength float agent separator process for controlling the cross-layer propagation of a fracturing fracture of claim 4, wherein the sand ratio of the float fluid is 5-6% in step S10.
8. The high-strength floating agent partition process for controlling the cross-layer propagation of the fracturing fracture as claimed in claim 4, wherein in step S20, the injection flow rate of the floating liquid is 3-5 m3/min。
9. The high strength proppant separator process for controlling the cross-bed propagation of a fracture of claim 4, wherein the first separator is formed for a period of at least 20 minutes in step S20.
10. The high-strength floating agent separator process for controlling the cross-layer propagation of the fracturing fracture as claimed in claim 4, wherein the thickness of the first separator is 5.2-17.5 cm.
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011226563.4A CN112410001B (en) | 2020-11-05 | 2020-11-05 | Floating agent and high-strength floating agent partition plate process for controlling fracturing fracture perforating expansion |
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| Application Number | Priority Date | Filing Date | Title |
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| CN202011226563.4A CN112410001B (en) | 2020-11-05 | 2020-11-05 | Floating agent and high-strength floating agent partition plate process for controlling fracturing fracture perforating expansion |
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| CN112410001A true CN112410001A (en) | 2021-02-26 |
| CN112410001B CN112410001B (en) | 2023-05-26 |
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Citations (8)
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