CN115074098A - Preparation and application of double-crosslinking nano reinforced foam gel water shutoff agent - Google Patents
Preparation and application of double-crosslinking nano reinforced foam gel water shutoff agent Download PDFInfo
- Publication number
- CN115074098A CN115074098A CN202210881561.1A CN202210881561A CN115074098A CN 115074098 A CN115074098 A CN 115074098A CN 202210881561 A CN202210881561 A CN 202210881561A CN 115074098 A CN115074098 A CN 115074098A
- Authority
- CN
- China
- Prior art keywords
- plugging
- agent
- water
- foam
- oil
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 83
- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 60
- 239000006260 foam Substances 0.000 title claims abstract description 40
- 238000002360 preparation method Methods 0.000 title claims abstract description 23
- 238000004132 cross linking Methods 0.000 title abstract description 5
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 34
- 239000002086 nanomaterial Substances 0.000 claims abstract description 19
- 238000000034 method Methods 0.000 claims abstract description 17
- 229920000642 polymer Polymers 0.000 claims abstract description 15
- 239000004088 foaming agent Substances 0.000 claims abstract description 14
- 239000003921 oil Substances 0.000 claims description 38
- 239000012071 phase Substances 0.000 claims description 29
- 238000012360 testing method Methods 0.000 claims description 13
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 12
- 230000000694 effects Effects 0.000 claims description 11
- 239000012452 mother liquor Substances 0.000 claims description 10
- 239000004576 sand Substances 0.000 claims description 10
- 238000003756 stirring Methods 0.000 claims description 9
- 238000006073 displacement reaction Methods 0.000 claims description 8
- 238000005187 foaming Methods 0.000 claims description 8
- 238000007865 diluting Methods 0.000 claims description 7
- 239000008208 nanofoam Substances 0.000 claims description 7
- 239000000243 solution Substances 0.000 claims description 7
- 230000035699 permeability Effects 0.000 claims description 6
- 239000007788 liquid Substances 0.000 claims description 5
- 229910052757 nitrogen Inorganic materials 0.000 claims description 5
- 238000011084 recovery Methods 0.000 claims description 5
- 239000008346 aqueous phase Substances 0.000 claims description 4
- 238000005086 pumping Methods 0.000 claims description 4
- 238000002474 experimental method Methods 0.000 claims description 2
- 239000010413 mother solution Substances 0.000 claims description 2
- 239000011435 rock Substances 0.000 claims description 2
- 239000010779 crude oil Substances 0.000 claims 2
- 238000010008 shearing Methods 0.000 claims 2
- 230000007423 decrease Effects 0.000 claims 1
- 238000011010 flushing procedure Methods 0.000 claims 1
- 230000007774 longterm Effects 0.000 claims 1
- 239000007764 o/w emulsion Substances 0.000 claims 1
- 239000002245 particle Substances 0.000 claims 1
- 239000004094 surface-active agent Substances 0.000 claims 1
- 239000002332 oil field water Substances 0.000 abstract 1
- 239000002994 raw material Substances 0.000 abstract 1
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 19
- 230000000903 blocking effect Effects 0.000 description 7
- 230000008901 benefit Effects 0.000 description 6
- 229920002401 polyacrylamide Polymers 0.000 description 6
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 description 5
- 229920002873 Polyethylenimine Polymers 0.000 description 5
- -1 alkyl glycoside Chemical class 0.000 description 5
- 239000002981 blocking agent Substances 0.000 description 5
- 229920001568 phenolic resin Polymers 0.000 description 5
- 239000005011 phenolic resin Substances 0.000 description 5
- 235000012239 silicon dioxide Nutrition 0.000 description 5
- 239000000377 silicon dioxide Substances 0.000 description 5
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 4
- WYYQVWLEPYFFLP-UHFFFAOYSA-K chromium(3+);triacetate Chemical compound [Cr+3].CC([O-])=O.CC([O-])=O.CC([O-])=O WYYQVWLEPYFFLP-UHFFFAOYSA-K 0.000 description 4
- GUJOJGAPFQRJSV-UHFFFAOYSA-N dialuminum;dioxosilane;oxygen(2-);hydrate Chemical compound O.[O-2].[O-2].[O-2].[Al+3].[Al+3].O=[Si]=O.O=[Si]=O.O=[Si]=O.O=[Si]=O GUJOJGAPFQRJSV-UHFFFAOYSA-N 0.000 description 4
- GVGUFUZHNYFZLC-UHFFFAOYSA-N dodecyl benzenesulfonate;sodium Chemical compound [Na].CCCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 GVGUFUZHNYFZLC-UHFFFAOYSA-N 0.000 description 4
- 239000008398 formation water Substances 0.000 description 4
- 229930182470 glycoside Natural products 0.000 description 4
- KWLMIXQRALPRBC-UHFFFAOYSA-L hectorite Chemical compound [Li+].[OH-].[OH-].[Na+].[Mg+2].O1[Si]2([O-])O[Si]1([O-])O[Si]([O-])(O1)O[Si]1([O-])O2 KWLMIXQRALPRBC-UHFFFAOYSA-L 0.000 description 4
- 229910000271 hectorite Inorganic materials 0.000 description 4
- 229910052901 montmorillonite Inorganic materials 0.000 description 4
- 229940080264 sodium dodecylbenzenesulfonate Drugs 0.000 description 4
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 description 3
- 230000008859 change Effects 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 230000018109 developmental process Effects 0.000 description 3
- 239000003129 oil well Substances 0.000 description 3
- 229940051841 polyoxyethylene ether Drugs 0.000 description 3
- 229920000056 polyoxyethylene ether Polymers 0.000 description 3
- 229910052938 sodium sulfate Inorganic materials 0.000 description 3
- 235000011152 sodium sulphate Nutrition 0.000 description 3
- 229920001285 xanthan gum Polymers 0.000 description 3
- 239000000230 xanthan gum Substances 0.000 description 3
- 229940082509 xanthan gum Drugs 0.000 description 3
- 235000010493 xanthan gum Nutrition 0.000 description 3
- 230000032683 aging Effects 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 229910001873 dinitrogen Inorganic materials 0.000 description 2
- 238000004090 dissolution Methods 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 230000002431 foraging effect Effects 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 229920006395 saturated elastomer Polymers 0.000 description 2
- 238000007789 sealing Methods 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 238000010828 elution Methods 0.000 description 1
- 150000002191 fatty alcohols Chemical class 0.000 description 1
- 229930182478 glucoside Natural products 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
Images
Classifications
-
- 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
- C09K8/5045—Compositions based on water or polar solvents containing inorganic compounds
-
- 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
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- 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
- C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
- C09K8/518—Foams
-
- 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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/10—Nanoparticle-containing well treatment fluids
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Inorganic Chemistry (AREA)
- Sealing Material Composition (AREA)
Abstract
The invention provides a preparation method and an application method of a double-crosslinking nano reinforced foam gel water shutoff agent, and relates to the field of oilfield chemistry. A preparation and application method of a selective water shutoff agent is mainly prepared from the following components in percentage by mass: 0.1-0.4% of nano material, 0.2-1.0% of polymer, 0.02-0.1% of cross-linking agent 1, 0.5-1% of cross-linking agent 2, 1% -2% of foaming agent and the balance of clear water. The clear water-based oil-water selective plugging agent is prepared from the raw materials, is simple in preparation process, is judged to be super-strong foam by a foam comprehensive index in a 105 ℃ oven, shows that the system is good in temperature resistance, has a plugging rate of less than 40% for an oil phase and a plugging rate of more than 90% for a water phase, has good selective plugging capability, and can meet the requirements of oil field water plugging.
Description
Technical Field
The invention relates to the field of oilfield chemistry for improving recovery efficiency, and particularly relates to a preparation method and application of a selective water shutoff agent.
Background
In the process of oil field development, the effluent of a main force oil production layer can bring problems of stratum energy loss, yield reduction, water treatment cost increase, equipment corrosion and the like to the oil field development work. Therefore, the water plugging operation on the high water-cut oil field becomes an effective means for the synergy of the oil field.
The purpose of water shutoff is to control the flow of water in an oil layer and change the flow direction of water in water displacement, improve the water displacement efficiency, try to make the water yield of an oil field reduced or stable within a period of time, so as to ensure the yield increase or stable yield of the oil field and improve the final recovery ratio of the oil field. At present, the cost of the foam plugging agent is low, the preparation method is simple, but the washout resistance and the temperature resistance of the conventional foam plugging agent are poor, so that the half-life period of the plugging agent in a formation liquid is short, and the water plugging effect is unstable. Therefore, the development of a double-crosslinking nano foam gel water shutoff agent with good temperature resistance and stable water shutoff effect is urgently needed.
Disclosure of Invention
The invention aims to solve the problems of short effective plugging period and low temperature resistance of the conventional foam plugging agent in oil well plugging, and provides a preparation and application method of a double-crosslinking nano reinforced foam gel plugging agent, which has the advantages of good temperature resistance and easiness in pumping, has strong selective plugging capability on oil and water, reduces the damage to oil layer mis-plugging and improves the oil production.
In order to achieve the purpose, the invention adopts the following technical scheme:
the invention relates to a foam gel selective water shutoff agent which is mainly prepared from the following components in percentage by mass: 0.1-0.4% of nano material, 0.2-1.0% of polymer, 0.02-0.1% of cross-linking agent 1, 0.5-1% of cross-linking agent 2, 1% -2% of foaming agent and the balance of clear water.
The nano material is any one of silicon dioxide, montmorillonite and hectorite; the polymer is any one of xanthan gum, acrylamide and polyacrylamide; the cross-linking agent 1 and the cross-linking agent 2 are any two of chromium acetate, polyethyleneimine and phenolic resin; the foaming agent is any one of alkyl glycoside, sodium dodecyl benzene sulfonate and fatty alcohol-polyoxyethylene ether sodium sulfate.
The invention also provides a preparation method of the selective water shutoff agent and a water shutoff method, and the preparation method mainly comprises the following steps:
s1: dissolving a certain mass percentage of nano material in 80ml of clear water, setting the rotating speed at 400r/min, and stirring until the nano material is fully dissolved;
s2: after the nano material is fully stirred and dissolved, adding the polymer, setting the rotating speed at 300-. Diluting the cross-linking agent 1 in 10ml of clear water, diluting the cross-linking agent 2 in another 10ml of clear water, and adding the diluted cross-linking agent 1 and the diluted cross-linking agent 2 into the stirred polymer solution for full dissolution;
s3: after the cross-linking agent is fully stirred and dissolved, adding a foaming agent, setting the rotating speed at 100r/min, and stirring for 0.5h to prepare an initial mother solution of the oil-water selective plugging agent;
s4: injecting 0.3PV mother liquor into a sand filling pipe or a rock core by adopting an underground foaming mode, and injecting nitrogen at the flow rate of 3ml/min to ensure that the mother liquor is completely foamed.
In the steps, the mass percent is calculated according to 100ml, and only a small part of solution is reserved in advance for diluting the cross-linking agent.
The preparation and water plugging method of the foam gel selective water plugging agent provided by the invention has the following effective benefits: the plugging rate of the oil phase in the stratum of about 1000mD is less than 40%, and the plugging rate of the water phase and the water phase in the stratum is more than 90%, so that the stratum has stronger oil-water selective plugging performance; the invention has the advantages of easy pumping, good temperature resistance, certain oil-water selective plugging characteristic and capability of meeting the water plugging requirement of an oil well.
Has the advantages that:
compared with the prior art, the invention has the following beneficial effects:
the plugging rate of the oil phase is less than 40 percent, and the plugging rate of the water phase of the formation is more than 90 percent, thus showing stronger oil-water selective plugging performance; easy pumping, good temperature resistance, certain strength and capability of meeting the water plugging requirement of an oil well.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings that are required to be used in the embodiments will be briefly described below, it should be understood that the following drawings only illustrate some embodiments of the present invention and therefore should not be considered as limiting the scope, and that for those skilled in the art, other relevant drawings can be obtained according to the drawings without inventive effort, wherein:
FIG. 1 is a graph showing the effect of the temperature resistance evaluation test of the plugging agent in example 1 of the present invention;
FIG. 2 is a graph of the oil phase blocking ratio versus displacement PV number for the example 1 blocking agent of the present invention;
FIG. 3 is a graph showing the change of the blocking rate of the water phase versus the displacement PV number of the blocking agent in example 1 of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the present invention more apparent, the present invention is further described in detail with reference to the following embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the invention and do not limit the invention.
Example (b):
the following is a detailed description of the selection of the selective water shutoff agent and the water shutoff method according to the embodiment of the present invention.
The invention relates to a foam gel selective water shutoff agent which is mainly prepared from the following components in percentage by mass: 0.1-0.4% of nano material, 0.2-1.0% of polymer, 0.02-0.1% of cross-linking agent 1, 0.5-1% of cross-linking agent 2, 1% -2% of foaming agent and the balance of clear water.
The nano material is any one of silicon dioxide, montmorillonite and hectorite; the polymer is any one of xanthan gum, acrylamide and polyacrylamide; the cross-linking agent 1 and the cross-linking agent 2 are any two of chromium acetate, polyethyleneimine and phenolic resin; the foaming agent is any one of alkyl glycoside, sodium dodecyl benzene sulfonate and fatty alcohol-polyoxyethylene ether sodium sulfate.
The invention also provides a selective water shutoff agent selecting and water shutoff method, and the preparation method mainly comprises the following steps:
s1: dissolving a certain mass percentage of nano materials in 90ml of clear water, setting the rotating speed at 400r/min, and stirring until the nano materials are fully dissolved;
s2: after the nano material is fully stirred and dissolved, adding the polymer, setting the rotating speed at 300-400r/min, and stirring for 1 h. Diluting the cross-linking agent 1 in 10ml of clear water, diluting the cross-linking agent 2 in another 10ml of clear water, and adding the diluted cross-linking agent 1 and the diluted cross-linking agent 2 into the stirred polymer solution for full dissolution;
s3: and after the cross-linking agent is fully stirred and dissolved, adding a foaming agent, setting the rotating speed at 100r/min, and stirring for 0.5h to prepare the initial mother liquor of the oil-water selective plugging agent.
In the steps, the mass percent is calculated according to 100ml, and only a small part of solution is reserved in advance for diluting the cross-linking agent.
In the invention, the method for judging the strength of the double-crosslinked nano foam gel is characterized in that the foam comprehensive index Fc is an index which can comprehensively evaluate the foam performance and is proposed by Daqing oil field research institute Zhao national seal et al, the foam life is calculated according to the change of the foam volume with time after the stirring is stopped, and FC is 0.75V 0 t 1/2 Wherein, FC is foam comprehensive index min ml; v0 is the maximum bubble volume of the system, ml; t is t 1/2 The half-life of the foam-elution is min. The foam comprehensive index considers two indexes of a foaming volume of a foam system and a liquid separation half-life period of the foam, so that the evaluation on the foaming performance of the foam system is more visual and reasonable. According to the size of the comprehensive foam index, the foam can be divided into four grades of super strength (more than 1500), strong strength (1500-1000), medium strength (1000-500) and weak strength (less than 500) in sequence.
All of the methods for determining the gel strength rating of the double cross-linked nanofoam in the present invention are based on the data provided above.
The features and properties of the present invention will be described in further detail with reference to examples.
Example 1:
the preparation method of the selective water shutoff agent selecting and water shutoff method of the embodiment is executed according to steps S1 to S3, and specifically comprises the following steps by mass percent: 0.1-0.4% of nano material (silicon dioxide), 0.2-1.0% of polymer (polyacrylamide), 0.02-0.1% of cross-linking agent 1 (chromium acetate), 0.5-1% of cross-linking agent 2 (phenolic resin) and 1-2% of foaming agent (alkyl glucoside).
Example 2:
the preparation method of the selective water shutoff agent selecting and water shutoff method of the embodiment is executed according to steps S1 to S3, and specifically comprises the following steps by mass percent: 0.1-0.4% of nano material ((2: 1 by mass of hectorite and silicon dioxide), 0.2-1.0% of polymer (3: 1 by mass of polyacrylamide and acrylamide), 0.02-0.1% of cross-linking agent 1 (polyethyleneimine), 0.5-1% of cross-linking agent 2 (phenolic resin), and 1-2% of foaming agent (2: 1 by mass of alkyl glycoside and sodium dodecyl benzene sulfonate).
Example 3:
in the method for selecting the selective water shutoff agent and for water shutoff, the preparation method is executed according to steps S1 to S3, and the method specifically includes the following steps in percentage by mass: 0.1-0.4% of nano material (2: 1 of hectorite and montmorillonite), 0.2-1.0% of polymer (3: 1 of polyacrylamide and acrylamide), 0.02-0.1% of cross-linking agent 1 (chromium acetate), 0.5-1% of cross-linking agent 2 (polyethyleneimine) and 1-2% of foaming agent (3: 1 of alkyl glycoside and fatty alcohol polyoxyethylene ether sodium sulfate).
Example 4:
the preparation method of the selective water shutoff agent selecting and water shutoff method of the embodiment is executed according to steps S1 to S3, and specifically comprises the following steps by mass percent: 0.1-0.4% of nano material ((2: 1 of silicon dioxide and montmorillonite), 0.2-1.0% of polymer (2: 1 of polyacrylamide to xanthan gum), 0.02-0.1% of cross-linking agent 1 (phenolic resin), 0.5-1% of cross-linking agent 2 (polyethyleneimine), and 1-2% of foaming agent (sodium dodecyl benzene sulfonate).
Test example 1:
the initial viscosity of the oil-and water-phase selective plugging agent in example 1 was measured, and 10ml of the sample of example 1 was measured for its viscosity at normal temperature using a brookfield viscometer.
Tests show that the initial viscosity of the mother liquor in example 1 is 330mPa.s, the initial viscosity is low, the plugging agent has good injectivity, and the plugging agent can enter the deep part of the stratum for plugging.
Test example 2:
the foaming property and temperature resistance of the selective water plugging agent for oil-water well in experimental example 1 were tested by pouring the mother liquor (100ml) of example 1 into a Waring-Blender mixer, stirring 100ml of the mother liquor at 6000rpm for 1min to completely foam it, pouring the foam into a sealed graduated cylinder, recording the maximum foaming volume, aging the graduated cylinder in an oven at 105 ℃, and continuously observing the temperature resistance of the selective water plugging agent for oil-water.
The temperature resistance results of the clear water-based oil-water selective plugging agent of example 1 are shown in fig. 1.
As shown by foamability and temperature resistance experiments, the maximum initial foaming volume of the plugging agent can reach 800ml, the foam volume gradually expands after the plugging agent is aged in an oven at 105 ℃, the foam volume is stabilized at 1100ml after the plugging agent is aged for 20 hours, the half-life of a liquid separation is not reached, the comprehensive foam index is more than 1500, the plugging agent can be determined to be super-strong foam, and the good plugging strength of the plugging agent is ensured.
Test example 3:
the oil phase plugging performance of example 1 was tested. The plugging agent (0.3PV) of example 1 was injected into a sand-packed pipe saturated with a simulated oil, and after the injection, nitrogen gas was injected at a flow rate of 3ml/min to completely foam the mother liquor. And sealing the sand filling pipe, putting the sand filling pipe into a 105 ℃ oven for aging, curing for 24 hours, then connecting the reverse sand filling pipe into a displacement device, displacing 10PV simulation oil, and testing the blocking rate of the blocking agent on the oil phase. It is to be noted that the simulated oil used in test example 3 had a viscosity of 4.98mPa.s at 105 ℃ and an oil phase permeability of 1350mD for the sand pack
The results of the oil phase plugging rate are shown in fig. 2.
From fig. 2, it can be seen that the plugging rate of the double-crosslinked nano-foam gel plugging agent to the oil phase is small, and the plugging rate of the plugging agent to the oil phase is gradually reduced as the simulated oil continues to be flushed. This is because the double cross-linked nanofoam gel formed in the large channels has large bubbles and is easily broken after being washed by the oil phase. When the displacement reaches 8PV, the blocking rate of the blocking agent to the oil tank is kept below 20%. From experimental results, the average plugging rate of the plugging agent to the oil phase is 35.9%, and the plugging agent has a good permeability recovery effect to the oil phase and can effectively protect a reservoir.
Test example 4:
the aqueous phase blocking performance of example 1 was tested. The plugging agent (0.3PV) of example 1 was injected into a sand-packed pipe saturated with formation water, and after the injection, nitrogen gas was injected at a flow rate of 3ml/min to completely foam the mother liquor. And sealing the sand filling pipe, putting the sand filling pipe into a 105 ℃ oven for aging, maintaining for 24 hours, reversely connecting the sand filling pipe into a displacement device, displacing 10PV formation water, and testing the blocking rate of the blocking agent to the water phase. It is noted that the formation water used in test example 3 had a mineralization of 24984mg/L and the water phase permeability of the sand pack was 1226 mD.
The results of the aqueous phase blocking ratio are shown in FIG. 3.
The double-cross-linked nano foam gel adopts an underground foaming mode, and water flooding is carried out after aging for 24 hours. As can be seen from FIG. 3, the plugging rate to the formation water is good under the condition of high permeability (1226mD), the average plugging rate to the water phase is more than 90%, and the water can be effectively plugged.
The preparation method of the selective water shutoff agent and the water shutoff method provided by the invention have the advantages of good temperature resistance and simple preparation, and are suitable for field preparation.
The embodiments described above are some, but not all embodiments of the invention. The detailed description of the embodiments of the present invention is not intended to limit the scope of the invention as claimed, but is merely representative of selected embodiments of the invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
Claims (7)
1. The invention relates to a foam gel selective water shutoff agent which is mainly prepared from the following components in percentage by mass: 0.1-0.4% of nano material, 0.2-1.0% of polymer, 0.02-0.1% of cross-linking agent 1, 0.5-1% of cross-linking agent 2, 1% -2% of foaming agent and the balance of clear water.
2. The preparation and water plugging method of the selective water plugging agent according to claim 1, wherein the preparation method comprises the following steps:
s1: dissolving a certain mass percentage of nano material in 80ml of clear water, setting the rotating speed at 400r/min, and stirring until the nano material is fully dissolved;
s2: after the nano material is fully stirred and dissolved, adding the polymer, setting the rotating speed at 300-;
s3: after the cross-linking agent is fully stirred and dissolved, adding a foaming agent, setting the rotating speed at 100r/min, and stirring for 0.5h to prepare an initial mother solution of the oil-water selective plugging agent;
s4: injecting 0.3PV mother liquor into a sand filling pipe or a rock core by adopting an underground foaming mode, and injecting nitrogen at the flow rate of 3ml/min to completely foam the mother liquor;
in the steps, the mass percent is calculated according to 100ml, and only a small part of solution is reserved in advance for diluting the cross-linking agent.
3. The preparation of the selective water shutoff agent according to claims 1-2, wherein the water shutoff system is composed of foaming agent and gel system, which provides shearing force for the mother liquid of the shutoff agent under the flushing of nitrogen, and the mother liquid forms a large amount of foam under the action of the shearing force, compared with the conventional nitrogen foam, the system is characterized in that the external phase of the foam is the gel phase instead of the water phase, so that the foam has longer half-life period and better stability, and has long-term effective shutoff effect, the Jamin effect and the shunting effect generated by the double-crosslinked nano foam gel are more prominent, the shutoff effect on the high-permeability flow channel is stronger, and the resistance factor of the channel is improved, the effect of large shutoff and small blockage is obvious, the foam is defoamed by oil after entering the low-permeability area, the released nitrogen has energizing effect, and the crude oil forms oil-in-water emulsion particles under the action of surfactant, the recovery ratio of crude oil is improved.
4. The preparation and use of the plugging agent according to claims 1-2, wherein the initial viscosity is 330mpa.s, the initial viscosity is low, the pumping is easy, the plugging agent can enter the deep part of the stratum for plugging, and the sweep efficiency is enlarged.
5. The temperature resistance test of the selective water shutoff agent according to claims 1-2, wherein the water shutoff agent is stable at 105 ℃ for more than 20h, and is evaluated as super-strong foam according to the comprehensive foam value, and the water shutoff agent has higher temperature resistance and stability.
6. The results of the experiments on oil phase plugging with the selective plugging agent according to claims 1-2, wherein in oil phase plugging, the average permeability of the plugging agent to the oil phase is less than 40%, and the plugging rate of the plugging agent to the oil phase gradually decreases as the simulated oil continues to be washed, and after displacement to 8PV, the plugging rate of the plugging agent to the oil phase is kept below 20%, which indicates that the plugging agent has better oil phase permeability recovery and low damage to the reservoir.
7. The results of the aqueous plugging test using the selective plugging agent according to claims 1-2, wherein the plugging agent has an average plugging rate of greater than 90% with respect to the aqueous phase and a better plugging effect with respect to the aqueous phase in the aqueous plugging test.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210881561.1A CN115074098A (en) | 2022-07-26 | 2022-07-26 | Preparation and application of double-crosslinking nano reinforced foam gel water shutoff agent |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202210881561.1A CN115074098A (en) | 2022-07-26 | 2022-07-26 | Preparation and application of double-crosslinking nano reinforced foam gel water shutoff agent |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN115074098A true CN115074098A (en) | 2022-09-20 |
Family
ID=83243674
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202210881561.1A Pending CN115074098A (en) | 2022-07-26 | 2022-07-26 | Preparation and application of double-crosslinking nano reinforced foam gel water shutoff agent |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN115074098A (en) |
Citations (10)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101798500A (en) * | 2010-04-01 | 2010-08-11 | 中国石油大学(华东) | Plugging agent with double plugging function and filling method thereof |
| CN104927817A (en) * | 2014-03-20 | 2015-09-23 | 中国石油化工股份有限公司 | Three-phase self-foaming water-plugging agent |
| CN108587585A (en) * | 2018-05-30 | 2018-09-28 | 中国石油大学(华东) | Profile-controlling and plugging agent and application, profile control and water plugging system and its preparation method and application |
| CN110846012A (en) * | 2019-11-25 | 2020-02-28 | 中国石油大学(北京) | Temperature-resistant foam gel and preparation method and application thereof |
| CN111269707A (en) * | 2020-03-05 | 2020-06-12 | 中国石油天然气股份有限公司 | Workover fluid and preparation method and application thereof |
| US10889745B1 (en) * | 2019-12-17 | 2021-01-12 | Southwest Petroleum University | Plugging agent with temperature-resistant, salt-resistant and high-expansion for plugging large fractures and preparation method thereof |
| US20210115317A1 (en) * | 2019-10-16 | 2021-04-22 | Southwest Petroleum University | Particulate profile control agent self-adaptive to size of formation pore throat and preparation method thereof |
| CN113337260A (en) * | 2021-05-31 | 2021-09-03 | 中石化南京化工研究院有限公司 | Cation gel deep profile control system and preparation method thereof |
| CN113464087A (en) * | 2021-07-29 | 2021-10-01 | 西南石油大学 | Selective water plugging method for bottom water reservoir high-water-cut oil well |
| CN114163984A (en) * | 2021-12-13 | 2022-03-11 | 西南石油大学 | Selection of selective water shutoff agent for oil well and water shutoff method |
-
2022
- 2022-07-26 CN CN202210881561.1A patent/CN115074098A/en active Pending
Patent Citations (10)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101798500A (en) * | 2010-04-01 | 2010-08-11 | 中国石油大学(华东) | Plugging agent with double plugging function and filling method thereof |
| CN104927817A (en) * | 2014-03-20 | 2015-09-23 | 中国石油化工股份有限公司 | Three-phase self-foaming water-plugging agent |
| CN108587585A (en) * | 2018-05-30 | 2018-09-28 | 中国石油大学(华东) | Profile-controlling and plugging agent and application, profile control and water plugging system and its preparation method and application |
| US20210115317A1 (en) * | 2019-10-16 | 2021-04-22 | Southwest Petroleum University | Particulate profile control agent self-adaptive to size of formation pore throat and preparation method thereof |
| CN110846012A (en) * | 2019-11-25 | 2020-02-28 | 中国石油大学(北京) | Temperature-resistant foam gel and preparation method and application thereof |
| US10889745B1 (en) * | 2019-12-17 | 2021-01-12 | Southwest Petroleum University | Plugging agent with temperature-resistant, salt-resistant and high-expansion for plugging large fractures and preparation method thereof |
| CN111269707A (en) * | 2020-03-05 | 2020-06-12 | 中国石油天然气股份有限公司 | Workover fluid and preparation method and application thereof |
| CN113337260A (en) * | 2021-05-31 | 2021-09-03 | 中石化南京化工研究院有限公司 | Cation gel deep profile control system and preparation method thereof |
| CN113464087A (en) * | 2021-07-29 | 2021-10-01 | 西南石油大学 | Selective water plugging method for bottom water reservoir high-water-cut oil well |
| CN114163984A (en) * | 2021-12-13 | 2022-03-11 | 西南石油大学 | Selection of selective water shutoff agent for oil well and water shutoff method |
Non-Patent Citations (1)
| Title |
|---|
| 易雄健;郭继香;杨矞琦: "耐高温油田堵水剂的研究进展", 应用化工, vol. 49, no. 04, pages 945 - 957 * |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Vossoughi | Profile modification using in situ gelation technology—a review | |
| CN112210357B (en) | W/O/W type multiple emulsion water shutoff system and preparation method thereof | |
| EP3059293B1 (en) | Zirconium dispersed-particle gel combination flooding system and preparation method thereof | |
| Guo et al. | Chemical water shutoff agents and their plugging mechanism for gas reservoirs: A review and prospects | |
| CN115074098A (en) | Preparation and application of double-crosslinking nano reinforced foam gel water shutoff agent | |
| Hao et al. | Using starch graft copolymer gel to assist the CO 2 huff-n-puff process for enhanced oil recovery in a water channeling reservoir | |
| CA2791134C (en) | Process for producing mineral oil from underground mineral oil deposits | |
| CN110886592B (en) | Oil-water well grading corrosion deblocking method | |
| CN114907826B (en) | Targeting deep profile control agent and preparation method and application thereof | |
| CN111154473A (en) | Blockage removal oil displacement agent and preparation method and application thereof | |
| CN114151048B (en) | Gas channeling prevention and oil displacement method for compact reservoir horizontal well | |
| CN115433555A (en) | Multiple emulsion composite profile control and flooding system and preparation method thereof | |
| CN111594116B (en) | In-situ emulsification oil displacement method for low-permeability reservoir | |
| CN114753818B (en) | Method for improving yield of thickened oil huff-puff well | |
| CN114806523A (en) | Multiple emulsion gel composite plugging regulating system and preparation method and application thereof | |
| Daryasafar et al. | CO 2-FOAM INJECTION FOR ENHANCING OIL RECOVERY: A BRIEF REVIEW | |
| US3315743A (en) | Aqueous solution flow in permeable earth formations | |
| CN113404459A (en) | Selective water plugging method for bottom water gas reservoir high-water-content gas well | |
| Seright et al. | Effect of CR³+ on the rheology of xanthan formulations in porous media: Before and after gelation | |
| Zhaoxia et al. | Study on prevention of gas channelling of acid-resistant gel foam in CO2 flooding of low permeability reservoir | |
| Wang et al. | Petroleum Science | |
| US9260955B2 (en) | Method of reducing zone permeability by in-situ formation gel of urotropin and urea in an aqueous solution | |
| CN112280544B (en) | Emulsion type precipitation profile control agent and preparation method and application thereof | |
| CN115324551B (en) | Fracturing method of hypotonic water-sensitive waxy reservoir | |
| CN113755148B (en) | Viscosity-reducing oil-displacing composition and composite oil-displacing agent |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| WD01 | Invention patent application deemed withdrawn after publication |
Application publication date: 20220920 |
|
| WD01 | Invention patent application deemed withdrawn after publication |