CN113088269A - Organic-inorganic composite water shutoff agent - Google Patents
Organic-inorganic composite water shutoff agent Download PDFInfo
- Publication number
- CN113088269A CN113088269A CN201911335385.6A CN201911335385A CN113088269A CN 113088269 A CN113088269 A CN 113088269A CN 201911335385 A CN201911335385 A CN 201911335385A CN 113088269 A CN113088269 A CN 113088269A
- Authority
- CN
- China
- Prior art keywords
- water shutoff
- organic
- inorganic composite
- composite water
- agent
- 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.)
- Granted
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 72
- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 46
- 239000002131 composite material Substances 0.000 title claims abstract description 18
- 229920002401 polyacrylamide Polymers 0.000 claims abstract description 40
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims abstract description 39
- 125000002091 cationic group Chemical group 0.000 claims abstract description 33
- 239000003921 oil Substances 0.000 claims abstract description 16
- 239000000377 silicon dioxide Substances 0.000 claims abstract description 15
- 239000003431 cross linking reagent Substances 0.000 claims abstract description 10
- 239000012760 heat stabilizer Substances 0.000 claims abstract description 10
- MUBZPKHOEPUJKR-UHFFFAOYSA-N Oxalic acid Chemical compound OC(=O)C(O)=O MUBZPKHOEPUJKR-UHFFFAOYSA-N 0.000 claims description 18
- UMGDCJDMYOKAJW-UHFFFAOYSA-N thiourea Chemical compound NC(N)=S UMGDCJDMYOKAJW-UHFFFAOYSA-N 0.000 claims description 16
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 12
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 12
- 239000005543 nano-size silicon particle Substances 0.000 claims description 12
- 235000012239 silicon dioxide Nutrition 0.000 claims description 12
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 claims description 11
- 239000005011 phenolic resin Substances 0.000 claims description 11
- 229920001568 phenolic resin Polymers 0.000 claims description 11
- GEHJYWRUCIMESM-UHFFFAOYSA-L sodium sulfite Chemical compound [Na+].[Na+].[O-]S([O-])=O GEHJYWRUCIMESM-UHFFFAOYSA-L 0.000 claims description 10
- 230000033558 biomineral tissue development Effects 0.000 claims description 9
- DWAQJAXMDSEUJJ-UHFFFAOYSA-M Sodium bisulfite Chemical compound [Na+].OS([O-])=O DWAQJAXMDSEUJJ-UHFFFAOYSA-M 0.000 claims description 8
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Natural products NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 claims description 8
- BDAGIHXWWSANSR-UHFFFAOYSA-N methanoic acid Natural products OC=O BDAGIHXWWSANSR-UHFFFAOYSA-N 0.000 claims description 8
- 235000010267 sodium hydrogen sulphite Nutrition 0.000 claims description 8
- 229920002873 Polyethylenimine Polymers 0.000 claims description 7
- 235000006408 oxalic acid Nutrition 0.000 claims description 6
- 235000010265 sodium sulphite Nutrition 0.000 claims description 5
- OSWFIVFLDKOXQC-UHFFFAOYSA-N 4-(3-methoxyphenyl)aniline Chemical compound COC1=CC=CC(C=2C=CC(N)=CC=2)=C1 OSWFIVFLDKOXQC-UHFFFAOYSA-N 0.000 claims description 4
- 235000011054 acetic acid Nutrition 0.000 claims description 4
- 239000007864 aqueous solution Substances 0.000 claims description 4
- 235000019253 formic acid Nutrition 0.000 claims description 4
- 238000000034 method Methods 0.000 claims description 4
- 238000002360 preparation method Methods 0.000 claims description 3
- 239000002994 raw material Substances 0.000 claims description 3
- -1 acrylic acid-maleic anhydride-acrylamide Chemical compound 0.000 claims description 2
- 235000015165 citric acid Nutrition 0.000 claims description 2
- 239000000203 mixture Substances 0.000 claims description 2
- 229920001897 terpolymer Polymers 0.000 claims description 2
- 239000003002 pH adjusting agent Substances 0.000 claims 1
- 238000011084 recovery Methods 0.000 abstract description 4
- 239000003208 petroleum Substances 0.000 abstract description 2
- 239000010779 crude oil Substances 0.000 abstract 1
- 239000000126 substance Substances 0.000 abstract 1
- 230000018044 dehydration Effects 0.000 description 14
- 238000006297 dehydration reaction Methods 0.000 description 14
- 238000003756 stirring Methods 0.000 description 13
- BHPQYMZQTOCNFJ-UHFFFAOYSA-N Calcium cation Chemical compound [Ca+2] BHPQYMZQTOCNFJ-UHFFFAOYSA-N 0.000 description 7
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 7
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 7
- 229910001424 calcium ion Inorganic materials 0.000 description 7
- 239000008367 deionised water Substances 0.000 description 7
- 229910021641 deionized water Inorganic materials 0.000 description 7
- 229910001425 magnesium ion Inorganic materials 0.000 description 7
- 239000011780 sodium chloride Substances 0.000 description 7
- 239000000499 gel Substances 0.000 description 5
- 230000018109 developmental process Effects 0.000 description 4
- 235000015110 jellies Nutrition 0.000 description 4
- 239000008274 jelly Substances 0.000 description 4
- 239000011148 porous material Substances 0.000 description 4
- 230000000694 effects Effects 0.000 description 3
- 150000003839 salts Chemical class 0.000 description 3
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 2
- ISWSIDIOOBJBQZ-UHFFFAOYSA-N Phenol Chemical compound OC1=CC=CC=C1 ISWSIDIOOBJBQZ-UHFFFAOYSA-N 0.000 description 2
- 229920006317 cationic polymer Polymers 0.000 description 2
- 239000002734 clay mineral Substances 0.000 description 2
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 description 2
- 230000001965 increasing effect Effects 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- KMUONIBRACKNSN-UHFFFAOYSA-N potassium dichromate Chemical compound [K+].[K+].[O-][Cr](=O)(=O)O[Cr]([O-])(=O)=O KMUONIBRACKNSN-UHFFFAOYSA-N 0.000 description 2
- GHMLBKRAJCXXBS-UHFFFAOYSA-N resorcinol Chemical compound OC1=CC=CC(O)=C1 GHMLBKRAJCXXBS-UHFFFAOYSA-N 0.000 description 2
- 238000005406 washing Methods 0.000 description 2
- WZCQRUWWHSTZEM-UHFFFAOYSA-N 1,3-phenylenediamine Chemical compound NC1=CC=CC(N)=C1 WZCQRUWWHSTZEM-UHFFFAOYSA-N 0.000 description 1
- 229930040373 Paraformaldehyde Natural products 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 235000019270 ammonium chloride Nutrition 0.000 description 1
- 229920006318 anionic polymer Polymers 0.000 description 1
- 239000012752 auxiliary agent Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000003111 delayed effect Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000003349 gelling agent Substances 0.000 description 1
- 235000010299 hexamethylene tetramine Nutrition 0.000 description 1
- 239000004312 hexamethylene tetramine Substances 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 229940018564 m-phenylenediamine Drugs 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 229920002866 paraformaldehyde Polymers 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000003381 stabilizer Substances 0.000 description 1
- 230000000007 visual effect Effects 0.000 description 1
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
- C09K8/506—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
-
- 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
- E21B43/20—Displacing by water
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
- Compositions Of Macromolecular Compounds (AREA)
Abstract
The invention discloses an organic-inorganic composite water shutoff agent, and relates to the technical field of chemical water shutoff and profile control of oil fields in petroleum engineering. The organic-inorganic composite water shutoff agent consists of the following components: cationic polyacrylamide, a cross-linking agent, modified nano-silica, a pH regulator, a heat stabilizer and water. The water shutoff agent has good thermal stability, can meet the requirements of high-temperature reservoir shutoff operation, and can remarkably improve the crude oil recovery ratio.
Description
Technical Field
The invention relates to a profile control agent for improving the oil yield and the recovery ratio in the oil field exploitation and development, a preparation method and application thereof, belonging to the technical field of oil exploitation auxiliary agents.
Background
Water drive development is one of the main technical means of petroleum development in China. At present, oil fields in China enter the middle and later stages of water flooding development, the oil fields are in a high water content stage, injected water can flow along high-permeability pore passages due to the heterogeneity of strata frequently, the permeability of reservoirs can be gradually increased along with the long-term washing of the injected water, the heterogeneity of the strata is more serious, and therefore the water can flow along the large pore passages more easily, invalid circulation is serious, a large amount of residual oil cannot be extracted, and the water flooding effect is reduced. In order to improve the water flooding effect and increase the recovery efficiency, high-permeability pore canals must be plugged. The water shutoff and profile control work of the oil field can be divided into water shutoff and water injection well profile control of the oil well, and both the water shutoff and the profile control are effective modes for plugging a high permeable zone, adjusting a water absorption profile, reducing water content and improving recovery ratio.
In the prior art, aiming at the problems of low efficiency and ineffective circulation of large-pore injected water, various researches on plugging regulating systems are developed in various oil fields, and polymer gels are the most widely used plugging agents at home and abroad. Among them, the polymer gel profile control agent having hydrolyzed polyacrylamide as a main agent is most used.
Such as: publication No. CN105860946A discloses a profile control and water shutoff system with controllable low-temperature gelling, which mainly comprises hydrolyzed polyacrylamide, paraformaldehyde, resorcinol and m-phenylenediamine.
Publication No. CN106634907A discloses a polyethyleneimine profile control water shutoff agent, which comprises partially hydrolyzed polyacrylamide, crosslinking agent polyethyleneimine, a delayed gelling agent, a stabilizing agent and the like.
Publication No. CN 102816558A discloses a deep water shutoff agent, which comprises partially hydrolyzed polyacrylamide, potassium dichromate, sodium sulfite, hexamethylenetetramine, phenol and ammonium chloride.
The profile control and water shutoff agent has obvious precipitation yield increasing effect mainly in medium and low temperature oil reservoirs (below 80 ℃), the profile control and water shutoff technology of high temperature oil reservoirs is immature, the failure rate is high, the low temperature water shutoff agent cannot meet the requirement of high temperature strata, and the water in the high temperature strata is seriously dewatered; in addition, most of the water shutoff agents adopt hydrolyzed polyacrylamide anionic polymers, clay minerals in oil reservoirs generally have electronegativity, and mutual repulsion between the clay minerals and the oil reservoirs is achieved, so that formed jelly is easy to desorb under the washing of injected water, and the plugging effect is lost.
Disclosure of Invention
The invention aims to provide a water shutoff agent which can overcome the defects of the prior art, is resistant to temperature and salt, has high gelling strength and can be suitable for medium-high temperature oil reservoirs.
The purpose of the invention is realized by the following technical scheme: an organic-inorganic composite water shutoff agent bag is prepared from the following raw materials of 0.15-0.75% of cationic polyacrylamide, 0.08-1% of cross-linking agent, 0.05-0.3% of modified nano silicon dioxide, 0-0.15% of pH regulator, 0.05-0.15% of heat stabilizer and the balance of water.
The modified nano silicon dioxide is acrylic acid-maleic anhydride-acrylamide terpolymer modified nano silicon dioxide.
The pH regulator is as follows: one or more of formic acid, acetic acid, oxalic acid and citric acid.
The heat stabilizer is as follows: one or a mixture of more of thiourea, sodium sulfite and sodium bisulfite.
0.15-0.70% of cationic polyacrylamide, preferably 0.20-0.60%.
0.08-0.80% of cross-linking agent, preferably 0.10-0.60%.
0.05-0.3% of modified nano silicon dioxide, preferably 0.06-0.2%.
The pH regulator comprises the following components in percentage by mass: 0 to 0.15 percent.
The mass percentage of the heat stabilizer is 0.05-0.10%, preferably 0.05-0.08%.
The preparation method of the organic-inorganic composite water shutoff agent comprises the following steps: preparing a cationic polyacrylamide aqueous solution, adding a cross-linking agent, modified nano-silica, a heat stabilizer and a pH regulator into the aqueous solution, and gelling to obtain the organic-inorganic composite water plugging agent.
The gelling temperature is 80-120 ℃, and the gelling time is 8-240 h.
The temperature-resistant salt-resistant gel plugging agent can be used at the temperature of 80-120 ℃ and the mineralization degree of not higher than 5 multiplied by 105And (5) applying mg/L oil reservoir water plugging.
The invention has the advantages that: (1) the modified nano silicon dioxide is introduced into the jelly, so that the strength, salt resistance and thermal stability of the jelly are improved, the jelly is hardly dehydrated at high temperature, and the gelling time is controllable; (2) the cationic polymer is used as a main agent, so that the cationic polymer can strongly act with negatively charged rocks, and the effective period of plugging is prolonged.
Detailed Description
In order to better understand the present invention, the following examples are further provided to illustrate the content of the present invention, but the content of the present invention is not limited to the following examples.
Example 1
Adding 0.25g of cationic polyacrylamide into 99.56g of deionized water, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.08g of water-soluble phenolic resin, 0.05g of modified nano-silica, 0.01g of formic acid and 0.05g of thiourea to obtain the water plugging agent, wherein the gelling time of the system at 80 ℃ is 100h, the dehydration rate in 270 days is 0.5%, and the elastic modulus is 15.0 Pa.
Example 2
Adding 0.60 cationic polyacrylamide into 97.70g of deionized water, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 1.00g of water-soluble phenolic resin, 0.3g of modified nano-silica, 0.10g of oxalic acid and 0.15g of thiourea to obtain the water plugging agent, wherein the gelling time of the system at 120 ℃ is 8h, the gel strength of the formed gel can reach I grade by adopting a visual code method, the dehydration rate in 270 days is 0.62%, and the elastic modulus is 17.1 Pa.
Example 3
Adding 0.15g of polyacrylamide into 99.66g of deionized water, continuously stirring until the polyacrylamide is completely dissolved, then adding 0.08g of water-soluble phenolic resin, 0.05g of modified nano-silica, 0.01g of oxalic acid and 0.05g of thiourea to obtain the water plugging agent, wherein the gelling time of the system at 80 ℃ is 240h, the dehydration rate in 270 days is 0.61%, and the elastic modulus is 10.1 Pa.
Example 4
Adding 0.60g of cationic polyacrylamide into 98.24g of deionized water, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.80g of water-soluble phenolic resin, 0.2g of modified nano-silica, 0.06g of acetic acid and 0.10g of sodium sulfite to obtain the water plugging agent, wherein the gelling time of the system at 80 ℃ is 8h, the dehydration rate in 270 days is 0.11%, and the elastic modulus is 19.3 Pa.
Example 5
Adding 0.45g of cationic polyacrylamide into 97.52g of deionized water, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.60g of water-soluble phenolic resin, 0.07g of modified nano-silica, 0.04g of citric acid and 0.08g of sodium bisulfite to obtain the water plugging agent, wherein the gelling time of the system at 120 ℃ is 24h, the dehydration rate in 270 days is 0.23%, and the elastic modulus is 15.3 Pa.
Example 6
Adding 0.65g of cationic polyacrylamide into 98.35g of deionized water, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.60g of polyethyleneimine, 0.3g of modified nano silicon dioxide and 0.10g of sodium bisulfite to obtain the water shutoff agent, wherein the system has the gelling time of 24 hours at 120 ℃, the dehydration rate of 0.13 percent in 270 days and the elastic modulus of 25.3 Pa.
Example 7
Adding 0.20g of cationic polyacrylamide into 99.6g of deionized water, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.10g of polyethyleneimine, 0.05g of modified nano-silica and 0.05g of sodium bisulfite to obtain the water shutoff agent, wherein the system has the gelling time of 96h at 110 ℃, the dehydration rate of 0.21 percent in 270 days and the elastic modulus of 14.4 Pa.
Example 8
At 97.75g the total degree of mineralization was 5X 105In mg/L saline (wherein the total of calcium ions and magnesium ions is 2X 10)5mg/L), adding 0.75g of cationic polyacrylamide, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.08g of water-soluble phenolic resin, 0.10g of nano silicon dioxide, 0.15g of oxalic acid and 0.15g of thiourea to obtain the water shutoff agent, wherein the gelling time of the system at 80 ℃ is 8h, the dehydration rate of 270 days is 0.06%, and the elastic modulus is 21.5 Pa.
Example 9
The total mineralization at 99.56g is 5X 105In mg/L saline (wherein the total of calcium ions and magnesium ions is 2X 10)5mg/L), adding 0.25g of cationic polyacrylamide, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.08g of water-soluble phenolic resin, 0.05g of nano silicon dioxide, 0.01g of formic acid and 0.05g of thiourea to obtain the water shutoff agent, wherein the gelling time of the system at 80 ℃ is 240h, the dehydration rate of 270 days is 0.24%, and the elastic modulus is 13.5 Pa.
Example 10
At 98.45g the total degree of mineralization is 5X 105In mg/L saline (wherein the total of calcium ions and magnesium ions is 2X 10)5mg/L), adding 0.65g of cationic polyacrylamide, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.60g of water-soluble phenolic resin, 0.1g of modified nano-silica, 0.10g of oxalic acid and 0.10g of thiourea to obtain the water shutoff agent, wherein the system has the gelling time of 12h at 120 ℃, the dehydration rate of 0.14 percent in 270 days and the elastic modulus of 19.8 Pa.
Example 11
The total mineralization at 99.47g is 5X 105In mg/L saline (wherein the total of calcium ions and magnesium ions is 2X 10)5mg/L), adding 0.20g of cationic polyacrylamide, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.108g of water-soluble phenolic resin, 0.10g of modified nano-silica, 0.01g of acetic acid and 0.05g of sodium sulfite to obtain the water plugging agent, wherein the system is subjected to gelling at 120 ℃ for 240 hours, the dehydration rate in 270 days is 0.69%, and the elastic modulus is 11.5 Pa.
Example 12
At 98.76g the total degree of mineralization was 5X 105In mg/L saline (wherein the total of calcium ions and magnesium ions is 2X 10)5mg/L), adding 0.60 cationic polyacrylamide, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.80g of water-soluble phenolic resin, 0.30g of modified nano-silica, 0.02g of citric acid and 0.08g of sodium bisulfite to obtain the water plugging agent, wherein the system is gelled for 8 hours at 120 ℃, the dehydration rate in 270 days is 0.19%, and the elastic modulus is 18.5 Pa.
Example 13
The total mineralization at 98.35g is 5X 105In mg/L saline (wherein the total of calcium ions and magnesium ions is 2X 10)5mg/L), adding 0.65 cationic polyacrylamide, continuously stirring until the cationic polyacrylamide is completely dissolved, then adding 0.60g of polyethyleneimine, 0.3g of modified nano-silica and 0.10g of sodium bisulfite to obtain the water shutoff agent, wherein the gelling time of the system at 120 ℃ is 32h, the dehydration rate in 270 days is 0.17%, and the elastic modulus is 27.6 Pa.
Example 14
The total mineralization at 99.6g is 5X 105In mg/L saline (wherein the total of calcium ions and magnesium ions is 2X 10)5mg/L), 0.20g of cationic polyacrylamide is added, and the process is continuedStirring to completely dissolve, then adding 0.10g of polyethyleneimine, 0.05g of modified nano-silica and 0.05g of sodium bisulfite to obtain the water shutoff agent, wherein the gelling time of the system at 110 ℃ is 142h, the dehydration rate in 270 days is 0.27%, and the elastic modulus is 16.5 Pa.
Claims (10)
1. An organic-inorganic composite water shutoff agent is characterized by being prepared from the following raw materials: based on the total mass of the raw materials, 0.15-0.75% of cationic polyacrylamide, 0.08-1% of cross-linking agent, 0.05-0.3% of modified nano silicon dioxide, 0-0.15% of pH regulator, 0.05-0.15% of heat stabilizer and the balance of water.
2. The organic-inorganic composite water shutoff agent according to claim 1, characterized in that the cationic polyacrylamide is 0.15% -0.70%; 0.08 to 0.80 percent of cross-linking agent; 0.05 to 0.3 percent of modified nano silicon dioxide; 0.05 to 0.10 percent of heat stabilizer.
3. The organic-inorganic composite water shutoff agent according to claim 2, characterized in that the cationic polyacrylamide accounts for 0.20-0.60%; 0.10 to 0.60 percent of cross-linking agent; 0.06% -0.2% of modified nano silicon dioxide; 0.05 to 0.08 percent of heat stabilizer.
4. The organic-inorganic composite water shutoff agent according to any of claims 1 to 3, characterized in that the crosslinking agent is: one of water-soluble phenolic resin and polyethyleneimine.
5. The organic-inorganic composite water shutoff agent according to any one of claims 1 to 3, characterized in that the modified nano-silica is: acrylic acid-maleic anhydride-acrylamide terpolymer modified nano silicon dioxide.
6. The organic-inorganic composite water shutoff agent according to any one of claims 1 to 3, characterized in that the pH adjusting agent is: one or more of formic acid, acetic acid, oxalic acid and citric acid.
7. The organic-inorganic composite water shutoff agent according to claim 1, characterized in that the heat stabilizer is: one or a mixture of more of thiourea, sodium sulfite and sodium bisulfite.
8. The method for preparing the organic-inorganic composite water shutoff agent according to claim 1, characterized by comprising the steps of: preparing a cationic polyacrylamide aqueous solution, adding a cross-linking agent, modified nano-silica, a heat stabilizer and a pH regulator into the aqueous solution, and gelling to obtain the organic-inorganic composite water plugging agent.
9. The preparation method of the organic-inorganic composite water shutoff agent according to claim 8, wherein the gelling temperature is 80-120 ℃, and the gelling time is 8-240 h.
10. The use of the organic-inorganic composite water shutoff agent according to claim 1, wherein the water shutoff agent has a mineralization degree of not higher than 5 x 10 at a temperature of 80 ℃ to 120 ℃5The method is applied to the profile control and water shutoff of the oil reservoir of mg/L.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911335385.6A CN113088269B (en) | 2019-12-23 | 2019-12-23 | Organic-inorganic composite water shutoff agent |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911335385.6A CN113088269B (en) | 2019-12-23 | 2019-12-23 | Organic-inorganic composite water shutoff agent |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN113088269A true CN113088269A (en) | 2021-07-09 |
| CN113088269B CN113088269B (en) | 2023-01-31 |
Family
ID=76663015
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201911335385.6A Active CN113088269B (en) | 2019-12-23 | 2019-12-23 | Organic-inorganic composite water shutoff agent |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN113088269B (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| 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 |
| CN114456783A (en) * | 2022-01-14 | 2022-05-10 | 西南石油大学 | Inorganic-organic composite profile control water shutoff agent and using method thereof |
Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106634908A (en) * | 2016-10-09 | 2017-05-10 | 中国石油化工股份有限公司 | Heat-resisting interpenetrating polymer network plural gel profile control agent and preparation method thereof |
| CN106832146A (en) * | 2017-01-26 | 2017-06-13 | 中国海洋石油总公司 | One kind can viscosify profile control agent and preparation method thereof |
| CN108531153A (en) * | 2018-05-03 | 2018-09-14 | 中国石油大学(华东) | A kind of high temperature resistant Petropols dispersion blocking agent and the preparation method and application thereof |
| 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 |
| CN110591679A (en) * | 2019-10-16 | 2019-12-20 | 西南石油大学 | Granular profile control agent adaptive to size of pore throat of stratum and preparation method thereof |
-
2019
- 2019-12-23 CN CN201911335385.6A patent/CN113088269B/en active Active
Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106634908A (en) * | 2016-10-09 | 2017-05-10 | 中国石油化工股份有限公司 | Heat-resisting interpenetrating polymer network plural gel profile control agent and preparation method thereof |
| CN106832146A (en) * | 2017-01-26 | 2017-06-13 | 中国海洋石油总公司 | One kind can viscosify profile control agent and preparation method thereof |
| CN108531153A (en) * | 2018-05-03 | 2018-09-14 | 中国石油大学(华东) | A kind of high temperature resistant Petropols dispersion blocking agent and the preparation method and application thereof |
| 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 |
| CN110591679A (en) * | 2019-10-16 | 2019-12-20 | 西南石油大学 | Granular profile control agent adaptive to size of pore throat of stratum and preparation method thereof |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| 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 |
| CN114456783A (en) * | 2022-01-14 | 2022-05-10 | 西南石油大学 | Inorganic-organic composite profile control water shutoff agent and using method thereof |
Also Published As
| Publication number | Publication date |
|---|---|
| CN113088269B (en) | 2023-01-31 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN104449618B (en) | A kind of heat-resistant salt-resistant high-temperature self-crosslinking in-situ polymerization water shutoff gel | |
| CN113088269B (en) | Organic-inorganic composite water shutoff agent | |
| CN103468230B (en) | Secondary cross-linking profile control profile control agent and compound method thereof and application | |
| CN110952952B (en) | Low-permeability reservoir deep profile control and flooding method | |
| CN109369848B (en) | Functional temperature-resistant salt-resistant plugging agent and preparation method thereof | |
| CN106675540A (en) | Temperature-resistant salt-resistant profile control plugging agent and preparation method thereof | |
| CN106947450B (en) | Deep profile control and flooding agent with low initial viscosity and preparation method thereof | |
| CN104017135A (en) | Method for preparing microbial polysaccharide modified copolymer gel plugging agent | |
| CN101880522B (en) | Inorganic-organic ternary composite plugging agent for oil extraction and preparation method | |
| CN109735315B (en) | Environment-friendly delayed crosslinking profile control agent for oil extraction and preparation method and application thereof | |
| CN102071003A (en) | High temperature resistant delay crosslinking polymer deep profile control agent | |
| CN111410943B (en) | Composite gel well killing rubber plug capable of being quickly gelatinized and weighted at high temperature and preparation method thereof | |
| CN112980412A (en) | Modifying and flooding agent suitable for high-temperature high-salinity heavy oil reservoir and preparation method thereof | |
| CN102603969B (en) | A kind of cementing properties GEL USED FOR PLUGGING WELL LOST CIRCULATION and preparation method thereof | |
| CN112175595B (en) | Temperature-resistant and salt-resistant profile control water shutoff agent | |
| RU2424426C1 (en) | Procedure for development of non-uniform reservoir | |
| CN105131921B (en) | A kind of salt-resisting high-temperature-resisting high intensity crosslinked gel plugging aqua | |
| CN113234425B (en) | Composite aluminum gel plugging agent for deep profile control of medium-low permeability oil reservoir and preparation method and application thereof | |
| CN105331345A (en) | Retarded foam gel for profile modification of oil field | |
| CN106928952B (en) | Delayed crosslinking polymer system | |
| CN114316932B (en) | High-temperature-resistance resident plugging agent | |
| CN114479798B (en) | Hydrophobic association polymer type plugging agent and preparation method and application thereof | |
| CN113249102B (en) | Slow cross-linking gel for profile control of medium-high temperature oil reservoir and preparation method thereof | |
| CN112457835B (en) | High-temperature-resistant salt-resistant composite plugging agent | |
| CN107793685B (en) | Crosslinked polymer weak gel and preparation method and application thereof |
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 | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |