CN113931607A - Injection control method of shielding temporary plugging agent and application thereof - Google Patents
Injection control method of shielding temporary plugging agent and application thereof Download PDFInfo
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- CN113931607A CN113931607A CN202010676662.6A CN202010676662A CN113931607A CN 113931607 A CN113931607 A CN 113931607A CN 202010676662 A CN202010676662 A CN 202010676662A CN 113931607 A CN113931607 A CN 113931607A
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- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 113
- 238000002347 injection Methods 0.000 title claims abstract description 60
- 239000007924 injection Substances 0.000 title claims abstract description 60
- 238000000034 method Methods 0.000 title claims abstract description 28
- 239000012530 fluid Substances 0.000 claims abstract description 159
- 238000004519 manufacturing process Methods 0.000 claims abstract description 8
- 239000002253 acid Substances 0.000 claims description 65
- 238000006073 displacement reaction Methods 0.000 claims description 32
- 239000000243 solution Substances 0.000 claims description 25
- 238000001914 filtration Methods 0.000 claims description 23
- 238000010276 construction Methods 0.000 claims description 19
- 230000004888 barrier function Effects 0.000 claims description 15
- 239000002981 blocking agent Substances 0.000 claims description 12
- 238000005260 corrosion Methods 0.000 claims description 8
- 230000007797 corrosion Effects 0.000 claims description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 7
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 5
- 230000000903 blocking effect Effects 0.000 claims description 5
- 239000003431 cross linking reagent Substances 0.000 claims description 5
- 239000003381 stabilizer Substances 0.000 claims description 5
- 239000002562 thickening agent Substances 0.000 claims description 5
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims description 3
- 238000011010 flushing procedure Methods 0.000 claims description 3
- 239000003112 inhibitor Substances 0.000 claims description 3
- 229910052500 inorganic mineral Inorganic materials 0.000 claims description 3
- 239000011707 mineral Substances 0.000 claims description 3
- 239000000203 mixture Substances 0.000 claims description 3
- 239000005011 phenolic resin Substances 0.000 claims description 3
- 229920001568 phenolic resin Polymers 0.000 claims description 3
- 230000000704 physical effect Effects 0.000 claims description 3
- 229920005989 resin Polymers 0.000 claims description 3
- 239000011347 resin Substances 0.000 claims description 3
- 239000004215 Carbon black (E152) Substances 0.000 claims description 2
- 229930195733 hydrocarbon Natural products 0.000 claims description 2
- 150000002430 hydrocarbons Chemical class 0.000 claims description 2
- 239000011435 rock Substances 0.000 abstract description 25
- 239000006185 dispersion Substances 0.000 abstract description 2
- 230000007774 longterm Effects 0.000 abstract description 2
- 208000010392 Bone Fractures Diseases 0.000 description 56
- 239000007788 liquid Substances 0.000 description 32
- 238000005516 engineering process Methods 0.000 description 12
- 238000012360 testing method Methods 0.000 description 8
- 238000009826 distribution Methods 0.000 description 7
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 239000011229 interlayer Substances 0.000 description 4
- 239000010410 layer Substances 0.000 description 4
- 239000000463 material Substances 0.000 description 4
- 230000002349 favourable effect Effects 0.000 description 3
- 238000004088 simulation Methods 0.000 description 3
- 239000004971 Cross linker Substances 0.000 description 2
- 230000002411 adverse Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000002955 isolation Methods 0.000 description 2
- 238000005086 pumping Methods 0.000 description 2
- 238000005406 washing Methods 0.000 description 2
- 208000003044 Closed Fractures Diseases 0.000 description 1
- 235000019738 Limestone Nutrition 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 230000003628 erosive effect Effects 0.000 description 1
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- 238000002474 experimental method Methods 0.000 description 1
- 239000006028 limestone Substances 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- -1 physical properties Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000003825 pressing Methods 0.000 description 1
- 230000001052 transient effect Effects 0.000 description 1
Classifications
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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
-
- 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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
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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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
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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
- C09K8/72—Eroding chemicals, e.g. acids
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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
- C09K8/72—Eroding chemicals, e.g. acids
- C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
-
- 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- 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
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
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- Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
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- General Life Sciences & Earth Sciences (AREA)
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- Organic Chemistry (AREA)
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- Geochemistry & Mineralogy (AREA)
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- General Chemical & Material Sciences (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
Abstract
The invention relates to an injection control method and application of a shielding temporary plugging agent, which comprises the following steps: step A: determining target crack parameters by adopting simulation software; and B: optimizing the injection parameters of the pre-fracturing fluid by adopting simulation software; and C: determining the area of the target crack to be covered by adopting simulation software according to the target crack parameters determined in the step A; step D: determining the dosage of the shielding temporary plugging agent according to the area of the target crack to be covered and the width of the target crack when the target crack is closed; step E: and D, determining the dosage of the base fluid of the fracturing fluid by adopting simulation software according to the injection parameters of the pre-fracturing fluid determined in the step B and the dosage of the shielding temporary plugging agent determined in the step D. The method can effectively improve the dispersion degree of the shielding temporary plugging agent in the fracture, form more dispersed un-corroded rock proppant body, disperse the stress concentration phenomenon under high pressure, and maintain the long-term stability of the acid-corroded fracture under high pressure, thereby prolonging the effective period of single well production.
Description
Technical Field
The invention belongs to the field of oilfield exploitation, and particularly relates to an injection control method of a shielding temporary plugging agent and application thereof.
Background
At present, the key technology in acid fracturing of deep or ultra-deep carbonate rock is how to form acid-etched cracks with high flow conductivity, and as long as the flow conductivity problem is solved, the deep penetration problem can be solved easily. Because, if the conductivity is lost, the longer acid-etched fractures will also fail, especially when the conductivity fails in the near-wellbore zone. If the flow conductivity fails at the position of the crack close to the end part or at a certain position in the middle part, the effective acid corrosion crack length is correspondingly greatly reduced.
How to improve the acid corrosion diversion capability of the carbonate rock is a worldwide problem, and particularly when the effective closing stress exceeds 6000Psi (41.3MPa), the diversion capability can be maintained for more than 180 days, which is quite difficult. Therefore, the current technology for improving the flow conductivity of acid fracturing fractures mainly adopts high-viscosity ground cross-linking acid or gelled acid, emulsified acid and the like, and adopts the technology of alternately injecting variable-viscosity acid liquid or alternately injecting high-viscosity fracturing liquid and low-viscosity acid liquid, and the like, although some effects are obtained, the effective period of acid fracturing can be maintained for more than 360 days, and the technology is not easy. The reason is that the acid fracturing technology comprises various high-viscosity acid solutions and an alternate injection technology, and is a pitting mode in nature, and the formed acid-etched fracture surface has low supporting strength under the action of high closing stress, so that the phenomenon of large-area collapse of the fracture can occur.
Therefore, a new acid fracturing technology capable of forming a local surface support mode, namely a self-supporting acid fracturing technology, is researched and proposed. The self-supporting acid fracturing technology is that acid liquid shielding materials with different areas are arranged on a fracture surface and can cover different parts of the fracture surface to prevent acid liquid from acid dissolution and corrosion effects on rocks of the fracture surface covered by the acid liquid, after a large amount of acid is injected in the later period, acid corrosion is mainly carried out on the exterior of the shielded rocks on the fracture surface, and the final fracture conductivity depends on the conductivity of the acid-etched fracture to support the whole fracture surface, namely the area of the shielded rocks. These rock areas are nearly evenly distributed throughout the fracture and the total bearing area is sufficient to overcome the intended closing stress effect. Obviously, the shielded fracture area has a critical value below which the fracture collapses and the conductivity decreases rapidly, and above which the fracture conductivity decreases, only one critical value ensuring maximum conductivity of the entire fracture. The core technology in this technology is how to control the distribution of the above-mentioned shielding material in the cracks. In the prior art, only the mode of alternate injection is simply adopted, so that the unnecessary cost increase is caused by the overlarge dosage of the temporary blocking agent, and the actual significance of shielding is lost because the width of a crack during injection is relatively large, the temporary blocking agent is difficult to be integrally pushed in the crack by displacement liquid, in other words, the temporary blocking agent is possibly distributed on most crack areas. Therefore, there is a need to develop a new control technique for effectively distributing the blocking agent in the fracture to solve the above limitations.
Disclosure of Invention
In order to solve the problems in the prior art, the invention provides an injection control method of a shielding temporary plugging agent, which is characterized in that the dynamic distribution characteristic of the shielding temporary plugging agent in a crack is calculated, the dosage, the injection speed and the crack closing time of the shielding temporary plugging agent are optimized, the shielding temporary plugging agent is dispersed on the wall surface of an artificial crack, and the thickness of the shielding temporary plugging agent adhered on the wall surface of the crack is larger, so that the pressure resistance of the un-corroded rock on the crack surface is improved, and the production period method of a single well is effectively increased.
The technical idea of the invention is as follows:
1) and the amount of the pre-fracturing fluid is reasonably optimized, and the filtration loss and the cost of the liquid shielding temporary plugging agent are further controlled. The method is characterized in that a certain viscosity of the pre-fracturing fluid is used for making a crack, in order to improve the crack making efficiency, the favorable condition that the crack expanding speed is high in the early stage of the crack making is utilized, when the length of the crack reaches 70% of the final length, the crack making efficiency of the fracturing fluid is obviously reduced, and at the moment, the volume of the fracturing fluid generally accounts for 20-30% of the total volume of the pre-fracturing fluid.
In addition, if the viscosity of the pad fluid is moderate and too high, the fluid loss is too slow, and the closing time of the crack is greatly increased. On the contrary, if the viscosity is too low, the seam forming efficiency is too low. The optimal parameters such as viscosity, volume and the like of the pre-fracturing fluid can be obtained by optimizing mature fracture propagation simulation software. Due to the influence of the fluid loss zone of the preposed fracturing fluid, the fluid loss of the shielding temporary plugging agent injected subsequently is relatively small, so that the dosage of the expensive shielding temporary plugging agent can be greatly reduced.
2) The injection timing of the blocking agent is shielded. Injecting after the crack is closed, namely performing closed injection of the shielding temporary plugging agent. The width of the crack after the crack is closed is relatively low, so that the whole crack surface can be filled with little volume of the shielding temporary plugging agent. If the length of the seam is 120m, the height of the seam is 40m and the width of the seam is 0.2mm, considering the isolation requirement of the displacement fluid, and assuming that the volume ratio of the displacement fluid to the shielding temporary plugging agent is 1:1, the volume of the shielding temporary plugging agent is 0.96m3. Even if the filtration depth of the shielding temporary plugging agent needs to be properly deep into the rock filtration zone for a certain thickness to increase the adhesion force of the shielding temporary plugging agent on the rock surface, the adhesion force is increased by 1 time, and the volume of the injected shielding temporary plugging agent is less than 2m3。
In addition, after the crack is closed or before the crack is closed, the displacement liquid is easy to push the shielding temporary plugging agent forwards in a piston mode, and the distribution form control of the shielding temporary plugging agent in the crack is facilitated. The volume and the cost of the shielding temporary plugging agent are reduced.
Meanwhile, the shielding temporary plugging agent should have a certain filtration loss thickness on the wall surface of the crack, such as 0.1mm or more, otherwise, because the existing pad fluid filtration zone can prevent the subsequent shielding temporary plugging agent from being attached along the wall surface of the crack, the adhesion strength of the shielding temporary plugging agent on the wall surface of the crack is not favorable, and the shielding temporary plugging agent is easy to be flushed away by subsequent acid liquor again. The specific fluid loss depth profiles (fluid loss depth distribution at different seams) under different liquid amounts can be obtained based on common fracturing design simulation software, the volumes of the fracturing liquid and the shielding temporary plugging agent can be adjusted, and the fluid loss depth difference of rocks of the shielding temporary plugging agent on the fracture surface can be considered to be more than 0.1mm as long as the fluid loss depth difference of two liquid systems at each seam is more than 0.1mm after injection.
Based on the above thought, the first aspect of the present invention provides a method for controlling injection of a shielding temporary plugging agent, comprising the steps of:
step A: determining target crack parameters by adopting simulation software;
and B: optimizing the injection parameters of the pre-fracturing fluid by adopting simulation software according to the target fracture parameters determined in the step A;
and C: determining the area of the target crack to be covered by adopting simulation software according to the target crack parameters determined in the step A;
step D: determining the dosage of the shielding temporary plugging agent according to the area of the target crack to be covered by the screen and the width of the target crack when the target crack is closed, which are determined in the step C;
step E: and D, determining the dosage of the base fluid of the fracturing fluid by adopting simulation software according to the injection parameters of the pre-fracturing fluid determined in the step B and the dosage of the shielding temporary plugging agent determined in the step D, so that the filtration depth of the shielding temporary plugging agent is greater than or equal to 0.1 mm.
According to some embodiments of the invention, the method further comprises evaluating the key reservoir parameters prior to step a.
According to some embodiments of the invention, the key reservoir parameters include mineral composition, physical properties, rock mechanics, tri-axial ground stress, and upper and lower barrier minimum level principal stress and natural fracture characteristics.
According to some embodiments of the invention, the key reservoir parameters may be obtained by comprehensively taking means of logging, testing, and analyzing the target zone and the upper and lower interlayer cores of the pilot hole under indoor simulated conditions of triaxial stress, temperature and the like.
According to some embodiments of the invention, in step a, a simulation software is used to determine the target fracture parameters based on the key reservoir parameters and the target hydrocarbon production.
According to some embodiments of the invention, the target fracture parameters include a fracture length, a fracture width, and a fracture height.
According to some embodiments of the invention, in step B, the injection parameters of the pre-fracturing fluid include the volume of the pre-fracturing fluid, the viscosity of the pre-fracturing fluid, the displacement of the pre-fracturing fluid, and the first fluid loss depth of the pre-fracturing fluid.
According to some embodiments of the invention, the viscosity of the pre-fracturing fluid is 30-40mpa.s, the viscosity of the pre-fracturing fluid is moderate, and if the viscosity is too high, the fluid loss is too slow, so that the closing time of the fracture is greatly increased. On the contrary, if the viscosity is too low, the seam forming efficiency is too low.
According to some embodiments of the invention, mature fracture propagation simulation software can be used to optimize and obtain optimal parameters such as viscosity and volume of the pre-fracturing fluid.
According to the invention, the fluid loss and the cost of the liquid shielding temporary plugging agent are controlled by reasonably optimizing the injection parameters of the pre-fracturing fluid, and meanwhile, due to the influence of the fluid loss zone of the pre-fracturing fluid, the fluid loss of the shielding temporary plugging agent injected subsequently is relatively small, so that the dosage of the expensive shielding temporary plugging agent can be greatly reduced.
According to some embodiments of the present invention, in step C, simulation software is used to determine the area of the target fracture to be covered according to the conductivity of the target fracture at the actual effective closing stress and temperature of the target layer.
According to some embodiments of the invention, the area corresponding to the maximum flow conductivity is taken as the area to cover the crack.
In some preferred embodiments of the present invention, the area of the covered fracture is 20 to 40% of the total area of the fracture.
According to some embodiments of the invention, in step D, the target crack is considered to be closed when the crack width is 0-0.2 mm.
According to some embodiments of the invention, the fracture width after fracture closure is relatively low, and thus the entire fracture face can be filled with very little volume of the barrier bridging agent. If the length of the seam is 120m, the height of the seam is 40m and the width of the seam is 0.2mm, considering the isolation requirement of the displacement fluid, and assuming that the volume ratio of the displacement fluid to the shielding temporary plugging agent is 1:1, the volume of the shielding temporary plugging agent is 0.96m3. Even if the filtration depth of the shielding temporary plugging agent needs to be properly deep into the rock filtration zone for a certain thickness to increase the adhesion force of the shielding temporary plugging agent on the rock surface, the adhesion force is increased by 1 time, and the volume of the injected shielding temporary plugging agent is less than 2m3. In addition, after the crack is closed or before the crack is closed, the displacement liquid is easy to push the shielding temporary plugging agent forwards in a piston mode, and the distribution form control of the shielding temporary plugging agent in the crack is facilitated. The volume and the cost of the shielding temporary plugging agent are reduced.
According to some embodiments of the invention, in step E, the fracturing fluid base fluid comprises a first fracturing fluid base fluid for carrying the barrier plugging agent and a second fracturing fluid base fluid as a displacement fluid
According to some embodiments of the present invention, in step E, a difference between the second fluid loss depth and the first fluid loss depth of the pre-fracturing fluid is simulated by using simulation software, and when the difference between the first fluid loss depth and the second fluid loss depth of the pre-fracturing fluid is greater than 0.1mm, the fluid loss depth of the temporary blocking shielding agent is considered to be greater than or equal to 0.1mm, where the second fluid loss depth is a fluid loss depth formed when the fracturing fluid base fluid and the temporary blocking shielding agent are injected.
In the invention, the shielding temporary plugging agent is controlled to have a certain filtration thickness on the wall surface of the crack, such as 0.1mm or more, otherwise, because the preposed fluid filtration zone exists, the subsequent shielding temporary plugging agent is prevented from being attached along the wall surface of the crack, the attachment strength of the shielding temporary plugging agent on the wall surface of the crack is not favorable, and the shielding temporary plugging agent is easy to be washed away by subsequent acid liquor again.
According to some embodiments of the present invention, specific fluid loss depth profiles (fluid loss depth distributions at different fracture sites) at different fluid volumes can be obtained based on common fracture design simulation software.
In some preferred modes of the invention, the volumes of the fracturing fluid base fluid and the shielding temporary plugging agent can be adjusted, so that the filtration depth difference of two fluid systems (a pre-fracturing fluid system and a system consisting of the fracturing fluid base fluid and the shielding temporary plugging agent) at each joint is more than 0.1mm after the two fluid systems are injected, and the filtration depth of the rock on the fracture surface of the shielding temporary plugging agent is considered to be more than 0.1 mm.
According to some embodiments of the present invention, the simulation software in the present invention is a commercial simulation software commonly used in the art, such as Stimplan, Gofher, etc.
According to some embodiments of the invention, the viscosity of the barrier temporary blocking agent before gelling is between 5 and 10 mpa.s.
According to some embodiments of the present invention, the viscosity of the barrier temporary plugging agent before gelling is controlled to be 5-10mpa.s to facilitate pumping and entering into the already closed fracture, for example, the viscosity is too high, so that the fracture resistance is large in the first time, and the fracture is easy to open, especially near the wellbore fracture. This easily causes the unfavorable situation that the dosage of the injected shielding temporary plugging agent is too large, and the form in the fracture is not easy to control, because the subsequent displacement fluid is possibly difficult to be in a piston type propulsion, the whole fracture surface is covered by the shielding temporary plugging agent, and the existence mechanism of the rock self-supporting fracture is lost.
According to some embodiments of the invention, the barrier temporary blocking agent has a viscosity after gelling of greater than 150 mpa.s.
According to some embodiments of the invention, the gel forming time is 60-90 min.
According to some embodiments of the invention, the gel formation time of the barrier plugging agent is adjusted according to the wellbore injection time of the barrier plugging agent to ensure that the gel formation time actually entering the fracture is 10-30 min.
In some preferred embodiments of the present invention, the temporary shielding blocking agent is prepared according to the requirement that the gel forming time of the first injection is long and the gel forming time of the second injection is short, and preferably, the temporary shielding blocking agent in the crack can be ensured to be simultaneously gel. The fine tuning may be specifically performed by the injection procedure and the time after the shield plugging agent is expected to reach the end of the crack for a certain distance.
In some embodiments of the present invention, the shielding temporary blocking agent comprises an organic resin prepolymer, a phenolic resin and a stabilizer.
According to some embodiments of the invention, the stabilizer is a stabilizer conventional in the art.
According to some embodiments of the present invention, the pad fracturing fluid is a pad fracturing fluid conventionally used in the art, preferably comprising water, a viscosifying agent, and a crosslinking agent.
According to some embodiments of the invention, the pre-fracturing fluid comprises 0.4 to 0.8 wt% of a viscosifying agent and 0.8 wt% of a cross-linking agent.
According to some embodiments of the present invention, the fracturing fluid base fluid is a fracturing fluid base fluid conventionally used in the art, preferably comprising water and a viscosifying agent.
According to some embodiments of the invention, the fracturing fluid base fluid comprises 0.4 to 0.8 wt% of a viscosifier.
A second aspect of the invention provides the use of the method of the first aspect in oilfield exploitation, particularly in barrier diverting injection.
A third aspect of the present invention provides a fracturing construction method, comprising the steps of:
s1: determining the injection parameters of the pre-fracturing fluid, the dosage of the shielding temporary plugging agent and the dosage of the fracturing fluid base fluid according to the method of the first aspect;
s2: performing pre-fracturing fluid injection construction according to the pre-fracturing fluid injection parameters determined in the step S1;
s3: after the pump is stopped for the first time, performing the slug type injection construction of the fracturing fluid base fluid and the shielding temporary plugging agent for multiple times, preferably 2-3 times, wherein the fracturing fluid base fluid comprises a first fracturing fluid base fluid used for carrying the shielding temporary plugging agent and a second fracturing fluid base fluid used as a displacing fluid;
s4: injecting low-viscosity flushing fluid for construction;
s5: and injecting the variable viscosity acid liquor for construction.
According to some embodiments of the invention, in step S2, the displacement of the pad fracturing fluid may be taken as the highest displacement under wellhead pressure limits.
According to some embodiments of the invention, the viscosity of the pre-fracturing fluid may be 30 to 40mpa.s in step S2.
According to some embodiments of the invention, in step S2, the volume of the pre-fracturing fluid is 300-400m3。
According to some embodiments of the invention, in step S2, the first time is a time required for the crack width to become 0-0.2mm after completion of step S3.
According to some embodiments of the invention, in step S3, the obtained minimum level principal stress of the target zone, i.e., fracture closure stress data, calculates the maximum allowable injection displacement of the wellhead, and then injects the first fracturing fluid base fluid, the second fracturing fluid base fluid and the barrier plugging agent in a slug manner according to the determined injection displacement.
According to some embodiments of the invention, the second fracturing fluid base fluid volume is the same as the first fracturing fluid base fluid volume.
According to some embodiments of the invention, the barrier transient blocking agent is present in an amount of 10-30% by volume of the first fracturing fluid.
According to some embodiments of the invention, the base fluid of the fracturing fluid has the same viscosity as the viscosity of the barrier temporary plugging agent, preferably 5 to 10 mpa.s.
According to some embodiments of the invention, the displacement of the low viscosity wash fluid is the same as the displacement of the pre-fracturing fluid in step S4.
According to some embodiments of the invention, the volume of the low viscosity rinse solution is 15-20m in step S43。
According to some embodiments of the invention, the low viscosity rinse solution comprises low viscosity slickwater in step S4.
According to some embodiments of the invention, the low viscosity slickwater has a viscosity of 1-2mpa.s in step S4.
According to some embodiments of the invention, in step S5, the viscosity-changing acid solution includes a first acid solution, a second acid solution, and a third acid solution.
According to some embodiments of the invention, the first acid liquid has a viscosity of 50 to 60 mpa.s.
According to some embodiments of the invention, the viscosity of the second acid liquor is 20-30 mpa.s.
According to some embodiments of the invention, the viscosity of the third acid liquor is 5 to 10 mpa.s.
According to some embodiments of the invention, in step S5, the volume of the first acid solution is 200-300m3。
According to some embodiments of the present invention, in step S5, the volume of the second acid solution is 100-200m3。
According to some embodiments of the invention, in step S5, the volume of the third acid liquid is 50-100m3。
According to some embodiments of the present invention, in step S5, the first acid solution, the second acid solution and the third acid solution are the same or different, and include hydrochloric acid, a thickener, a cross-linking agent and a corrosion inhibitor.
According to some embodiments of the invention, the acid liquor composition comprises 20 wt% HCl, 0.5-0.8 wt% thickener, 0.6-1.0 wt% crosslinker, and 3.0 wt% corrosion inhibitor.
According to some embodiments of the present invention, the viscosity of the first acid liquid, the second acid liquid, and the third acid liquid may be controlled by adjusting the ratio of the thickener and the cross-linker.
According to some embodiments of the invention, the first acid solution crosslinks the acid.
According to some embodiments of the invention, the second acid liquid is VES acid.
According to some embodiments of the invention, the third acid liquid is gelled acid.
According to some embodiments of the invention, in step S5, the displacement of the acid liquid with variable viscosity is the highest value under wellhead pressure limit.
According to some embodiments of the present invention, the step S6 further includes steps of S6-1 replacement work, S6-2 construction of other sections, and S6-3 post-press drainage, testing, normal production, etc.
According to some embodiments of the invention, in the S6-1 displacement operation, the displacement fluid is low-viscosity slickwater with the viscosity of 2-3mPa.s and the volume of 130-150% of the current section of the well bore, so as to reduce the excessive corrosion effect of the near-well bore crack and the adverse effect of the possible crack opening collapse on the flow conductivity of the crack. The highest value of the displacement under wellhead pressure limiting is taken.
The invention provides a novel injection control technology of a shielding temporary plugging agent for forming self-supporting cracks in carbonate rock acid fracturing, which can effectively improve the dispersion degree of the shielding temporary plugging agent in the cracks, form a more dispersed non-corroded rock propping agent body, disperse the stress concentration phenomenon under high pressure, and maintain the long-term stability of the acid-corroded cracks under high pressure, thereby prolonging the effective period of single-well production.
Detailed Description
The invention will now be further illustrated by means of specific examples, but it will be understood that the scope of the invention is not limited thereto.
The specific measures of the invention are as follows:
(1) evaluation of key reservoir parameters of carbonate rock: mainly comprises mineral components, physical properties, rock mechanics, three-dimensional ground stress, minimum horizontal main stress of an upper interlayer and a lower interlayer, natural crack characteristics and the like. The core testing and analyzing device can be obtained by comprehensively adopting the means of testing and analyzing the rock cores of the target layer and the upper and lower interlayer of the logging, testing and pilot hole well under the conditions of indoor simulation of triaxial stress, temperature and the like.
(2) Preparing a shielding temporary plugging agent: according to the requirement that the gel forming time is 60-90min (the injection time of a shaft is properly adjusted, the gel forming time actually entering the fracture is controlled to be 10-30min), the gel forming time of the first injection is long, and the gel forming time of the second injection is short, the shielding temporary plugging agent in the fracture can be ensured to be synchronously gel. The fine tuning may be specifically performed by the injection procedure and the time after the shield plugging agent is expected to reach the end of the crack for a certain distance. The viscosity before gelling is controlled to be 5-10mPa.s so as to be convenient for pumping and entering the closed crack, if the viscosity is too high, the resistance of entering the crack is large, and the crack is easy to openEspecially near the wellbore fracture. This easily causes the unfavorable situation that the dosage of the injected shielding temporary plugging agent is too large, and the form in the fracture is not easy to control, because the subsequent displacement fluid is possibly difficult to be in a piston type propulsion, the whole fracture surface is covered by the shielding temporary plugging agent, and the existence mechanism of the rock self-supporting fracture is lost. The specific preparation volume can be 1-2m according to the requirement of thought 2)3And the surplus is 30-50% in consideration of field adjustment.
(3) Experimental determination of total area covered by the shielding temporary plugging agent: simulating the flow conductivity and the change of the total area covered by different shielding temporary plugging agents under the actual effective closing stress and temperature of a target layer, and taking the area corresponding to the maximum flow conductivity as the total area covered by the shielding temporary plugging agents, wherein the area is generally 20-40% of the area of the artificial crack.
(4) Optimizing injection parameters of the pre-fracturing fluid and simulating a section of a fluid loss zone: the fracture length and fluid loss zone distribution along the length of the fracture under different pad volumes were simulated using commercial simulation software commonly used in fracturing, such as Stimplan, Gofher, etc. The parameters such as the discharge capacity and the like can be the highest discharge capacity under the pressure limiting of a wellhead, the seam length requirement and the like are generally determined based on a carbonate oil and gas reservoir yield prediction model, the volume of the pre-fracturing fluid is determined according to the parameters, and the viscosity of the pre-fracturing fluid can be 30-40 mPa.s.
(5) And (3) determining the injection time of the shielding temporary plugging agent: according to the requirement of the idea 2), on the basis of the parameters optimized in the step 3), adding pump stopping time after the injection parameters, performing multiple times of circulating calculation, simulating the change of the crack width under different pump stopping time, and finding out the pump stopping time when the crack width is close to 0 or in the range of 0.1-0.2mm, namely the optimal pump stopping time.
The filtration depth (rock depth on the wall surface of the crack) of the shielding temporary plugging agent is at least 0.1mm, and the filtration depth of the shielding temporary plugging agent at different pump stopping time after the injection is finished can be simulated on the basis of the injection program of the step 4), and the filtration depth is about 0.1mm larger than that of the step 4).
(6) Pre-fracturing fluid injection construction: the pre-fracturing fluid parameter determined in the step 4) is referred to, and the fluid quantity is generally 300-400m3。
(7) Shielding the temporary plugging agent by slug injection construction: calculating the maximum allowable injection displacement of the wellhead according to the data of the minimum horizontal principal stress of the target layer, namely the fracture closure stress obtained in the step 1). Then, the shielding temporary plugging agent and the displacement liquid with the same viscosity (the same is 5-10mPa.s) as the base liquid are respectively injected according to the determined injection discharge capacity in a slug mode. The specific volume ratio of the two is matched with the coverage area of the shielding temporary plugging agent obtained in the step 3) in advance.
(8) Injecting low-viscosity flushing fluid for construction: injecting low-viscosity slippery water washing liquid with the viscosity of 1-2mPa.s, wherein the discharge capacity can be obtained in the step 6), strictly controlling the crack not to open for two times, and the volume can be 15-20m3, so that the shielding material in the crack is more dispersed in the height direction of the crack.
(9) Injecting variable-viscosity acid liquor: and on the basis of the gelling time in the step 2), determining whether the construction in the step 8) needs waiting time or not by combining the construction finishing time in the step 7). Then, according to the reservoir temperature and the subsequent crack temperature field simulation result of injecting liquid with different volumes, the liquid is cut for 1.5h indoors, and the viscosity under 170-1/s is respectively 50-60mPa.s, 20-30mPa.s, 5-10mPa.s and the like, and corresponding acid liquid formulas are respectively configured. Respectively injecting 200-300m3, 100-200m3 and 50-100m3 in sequence, and taking the highest value of the displacement under the wellhead pressure limit.
(10) And (4) performing displacement operation, namely taking low-viscosity slick water with the viscosity of 2-3mPa.s and the volume of 130-150% of the current section of the well bore to reduce the excessive erosion effect of the near well bore crack and the adverse influence of possible crack collapse on the flow conductivity of the crack. The highest value of the displacement under wellhead pressure limiting is taken.
(11) And (5) constructing other sections, and repeating the steps 6) to 10) until all sections are constructed.
(12) And performing the links of liquid discharge, test, normal production and the like after pressing according to the conventional flow and parameters.
Example 1
The construction is carried out by the method provided by the invention at the well depth of 6324 meters and the temperature of 160 ℃ in a certain carbonate rock A well in Xinjiang. According to the experiment, the maximum horizontal main stress of the well is 152MPa, the minimum horizontal main stress is 127MPa, and the lithology is mainly limestone. And preparing a shielding temporary plugging agent according to the reservoir temperature (160 ℃), wherein the shielding temporary plugging agent comprises an organic resin prepolymer, phenolic resin and a stabilizer. The viscosity of the shielding temporary plugging agent before gelling is 5mPa.s, and the gelling time is 65 min.
According to the test of the diversion capability of the acid-etched fracture rock slab, the covering proportion of the shielding temporary plugging agent on the fracture surface needs to reach 30 percent, and the dosage of the shielding temporary plugging agent is 2m3. The acid-etched fracture of the well is calculated to be 127m according to the stratum parameter simulation, and the volume of the pre-fracturing fluid is 350m3The viscosity of the pad solution was 33 mPa.s. When the pump stopping time after the injection of the pad fluid is 18min, the crack width is 0.12mm, and the injection time of the shielding temporary plugging agent is the moment. When the total amount of the liquid carrying the shielding temporary plugging agent and the displacing liquid is 40m3The fluid loss depth at this stage is up to 0.1mm greater than the fluid loss depth of the pad.
And (3) construction stage: at 6m3Permin displacement injection pre-fracturing fluid 350m3After construction, the pump is stopped for 18min, and then the distance between the two ends is 2m3Permin discharge volume injection carrying shielding temporary plugging agent 1m3Base fluid (fluid viscosity: 5mPa.s) of fracturing fluid (10 m)3Changed to 2m3Permin displacement injection fracturing fluid base fluid 10m3As a displacement fluid, then at 2m3Permin discharge volume injection carrying shielding temporary plugging agent 1m3Base fluid (fluid viscosity: 5mPa.s) of fracturing fluid (10 m)3Changed to 2m3Permin displacement injection fracturing fluid base fluid 10m3As a displacement fluid. Then at 6m3The low-viscosity slippery water washing liquid with the viscosity of 1mPa.s is injected at the discharge amount of 20 m/min3. Then using 6m3Injecting 50mPa.s acid solution 250m per min3，6m3Injecting 25mPa.s acid liquor 150m per min3，6m3Injecting 5mPa.s acid liquor 80m per min3. Finally using 6m3Injecting low-viscosity slickwater with discharge capacity of 3mPa.s for 80 m/min3(wellbore volume 58m3)。
By implementing the method, the test yield after the well pressure is 127.5t/d, which is improved by 34 percent compared with the yield before the well is pressed, and the yield is still 102.5t/d after 4 months of production and is only reduced by 19.6 percent.
It should be noted that the above-mentioned embodiments are only for explaining the present invention, and do not set any limit to the present invention. The present invention has been described with reference to exemplary embodiments, but the words which have been used herein are words of description and illustration, rather than words of limitation. The invention can be modified, as prescribed, within the scope of the claims and without departing from the scope and spirit of the invention. Although the invention has been described herein with reference to particular means, materials and embodiments, the invention is not intended to be limited to the particulars disclosed herein, but rather extends to all other methods and applications having the same functionality.
Claims (10)
1. A shielding temporary plugging agent injection control method comprises the following steps:
step A: determining target crack parameters by adopting simulation software;
and B: optimizing the injection parameters of the pre-fracturing fluid by adopting simulation software according to the target fracture parameters determined in the step A;
and C: determining the area of the target crack to be covered by adopting simulation software according to the target crack parameters determined in the step A;
step D: determining the dosage of the shielding temporary plugging agent according to the area of the target crack to be covered and the width of the target crack when the target crack is closed, which are determined in the step C;
step E: and D, determining the dosage of the base fluid of the fracturing fluid by adopting simulation software according to the injection parameters of the pre-fracturing fluid determined in the step B and the dosage of the shielding temporary plugging agent determined in the step D, so that the filtration depth of the shielding temporary plugging agent is greater than or equal to 0.1 mm.
2. The method of claim 1, further comprising evaluating key reservoir parameters prior to step a, preferably the key reservoir parameters include mineral composition, physical properties, petromechanics, tri-axial ground stress, and upper and lower barrier minimum level principal stress and natural fracture characteristics.
3. The method according to claim 1 or 2, wherein in step a, target fracture parameters are determined by using simulation software according to key reservoir parameters and target hydrocarbon production, preferably, the target fracture parameters comprise fracture length, fracture width and fracture height;
and/or in the step B, the injection parameters of the pre-fracturing fluid comprise the volume of the pre-fracturing fluid, the viscosity of the pre-fracturing fluid, the discharge capacity of the pre-fracturing fluid and the first fluid loss depth of the pre-fracturing fluid;
and/or in the step C, determining the area of the target crack to be covered according to the flow conductivity of the target crack under the actual effective closing stress and temperature of the target layer by adopting simulation software, preferably taking the area corresponding to the maximum flow conductivity as the area of the target crack to be covered, and more preferably taking the area of the target crack to be covered as 20-40% of the total area of the target crack;
and/or, in the step D, when the width of the target crack becomes 0-0.2mm, the target crack is considered to be closed;
and/or in the step E, the base fluid of the fracturing fluid comprises a first base fluid of the fracturing fluid for carrying the shielding temporary plugging agent and a second base fluid of the fracturing fluid as a displacement fluid;
and/or simulating the difference value between the second filtration depth and the first filtration depth of the pre-fracturing fluid by adopting simulation software, wherein when the difference value between the first filtration depth and the second filtration depth of the pre-fracturing fluid is greater than 0.1mm, the filtration depth of the shielding temporary plugging agent is considered to be greater than or equal to 0.1mm, and the second filtration depth is the filtration depth formed when the fracturing fluid base fluid and the shielding temporary plugging agent are injected.
4. The method according to any one of claims 1 to 3, wherein the viscosity of the temporary blocking shielding agent before gelling is 5 to 10mPa.s, the viscosity after gelling is greater than 150mPa.s, and the gelling time is 60 to 90min, preferably the gelling time of the temporary blocking shielding agent is adjusted according to the wellbore injection time of the temporary blocking shielding agent to ensure that the gelling time actually entering the fracture is 10 to 30 min.
5. The method of any one of claims 1-4, wherein the pre-fracturing fluid comprises water, a viscosifying agent, and a crosslinking agent;
and/or the base fluid of the fracturing fluid comprises water and a thickening agent, preferably the viscosity of the base fluid of the fracturing fluid is the same as that of the shielding temporary plugging agent, and more preferably 5-10 mPa.s.
6. The method of any one of claims 1-5, wherein the shielding temporary blocking agent comprises an organic resin prepolymer, a phenolic resin, and a stabilizer.
7. Use of the method according to any one of claims 1-6 in oilfield exploitation, in particular in barrier diverting injection.
8. A fracturing construction method comprises the following steps:
s1: determining pre-fracturing fluid injection parameters, the amount of a barrier diverting agent, and the amount of a fracturing fluid base fluid according to the method of any of claims 1-6;
s2: performing pre-fracturing fluid injection construction according to the pre-fracturing fluid injection parameters determined in the step S1;
s3: after the pump is stopped for the first time, performing the slug type injection construction of the fracturing fluid base fluid and the shielding temporary plugging agent for multiple times, preferably 2-3 times, wherein the fracturing fluid base fluid comprises a first fracturing fluid base fluid used for carrying the shielding temporary plugging agent and a second fracturing fluid base fluid used as a displacing fluid;
s4: injecting low-viscosity flushing fluid for construction;
s5: and injecting the variable viscosity acid liquor for construction.
9. The method of claim 8, wherein in step S3, the first time is a time required for the crack width to become 0-0.2mm after completion of step S2;
and/or the dosage of the shielding temporary plugging agent is 10-30% of the volume of the first fracturing base fluid, and the volume of the first fracturing base fluid is the same as that of the second fracturing base fluid.
10. The method according to claim 8 or 9, wherein the low viscosity rinse comprises a low viscosity slickwater, preferably having a viscosity of 1-2 mpa.s;
and/or the variable viscosity acid solution comprises a first acid solution, a second acid solution and a third acid solution, wherein the viscosity of the first acid solution is 50-60mPa.s, the viscosity of the second acid solution is 20-30mPa.s, the viscosity of the third acid solution is 5-10mPa.s, and preferably, the first acid solution, the second acid solution and the third acid solution are the same or different in type and comprise hydrochloric acid, a thickening agent, a cross-linking agent and a corrosion inhibitor.
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