CN116285934B - Gel channeling inhibitor suitable for expanding sweep volume of carbon dioxide flooding of ultralow permeability reservoir and application thereof - Google Patents
Gel channeling inhibitor suitable for expanding sweep volume of carbon dioxide flooding of ultralow permeability reservoir and application thereof Download PDFInfo
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- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 224
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 112
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 112
- 230000035699 permeability Effects 0.000 title claims abstract description 60
- 230000005465 channeling Effects 0.000 title abstract description 49
- 239000003112 inhibitor Substances 0.000 title abstract description 8
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 67
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 47
- 150000003512 tertiary amines Chemical class 0.000 claims abstract description 27
- -1 alkyl bicarbonate Chemical compound 0.000 claims abstract description 17
- 239000003349 gelling agent Substances 0.000 claims abstract description 6
- 150000003973 alkyl amines Chemical class 0.000 claims abstract description 5
- 238000004513 sizing Methods 0.000 claims abstract description 3
- ABBQHOQBGMUPJH-UHFFFAOYSA-M Sodium salicylate Chemical compound [Na+].OC1=CC=CC=C1C([O-])=O ABBQHOQBGMUPJH-UHFFFAOYSA-M 0.000 claims description 8
- 229960004025 sodium salicylate Drugs 0.000 claims description 8
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 6
- ONLRKTIYOMZEJM-UHFFFAOYSA-N n-methylmethanamine oxide Chemical compound C[NH+](C)[O-] ONLRKTIYOMZEJM-UHFFFAOYSA-N 0.000 claims description 5
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims description 4
- NHLUVTZJQOJKCC-UHFFFAOYSA-N n,n-dimethylhexadecan-1-amine Chemical compound CCCCCCCCCCCCCCCCN(C)C NHLUVTZJQOJKCC-UHFFFAOYSA-N 0.000 claims description 4
- VMHLLURERBWHNL-UHFFFAOYSA-M Sodium acetate Chemical compound [Na+].CC([O-])=O VMHLLURERBWHNL-UHFFFAOYSA-M 0.000 claims description 3
- SYELZBGXAIXKHU-UHFFFAOYSA-N dodecyldimethylamine N-oxide Chemical compound CCCCCCCCCCCC[N+](C)(C)[O-] SYELZBGXAIXKHU-UHFFFAOYSA-N 0.000 claims description 3
- ONHFWHCMZAJCFB-UHFFFAOYSA-N myristamine oxide Chemical compound CCCCCCCCCCCCCC[N+](C)(C)[O-] ONHFWHCMZAJCFB-UHFFFAOYSA-N 0.000 claims description 3
- 239000001632 sodium acetate Substances 0.000 claims description 3
- 235000017281 sodium acetate Nutrition 0.000 claims description 3
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 3
- PRWXGRGLHYDWPS-UHFFFAOYSA-L sodium malonate Chemical compound [Na+].[Na+].[O-]C(=O)CC([O-])=O PRWXGRGLHYDWPS-UHFFFAOYSA-L 0.000 claims description 3
- 239000004280 Sodium formate Substances 0.000 claims description 2
- 229950010007 dimantine Drugs 0.000 claims description 2
- TYJXKGNJOSVQCP-UHFFFAOYSA-N n-[2-[acetyl(methyl)amino]ethyl]-n-methylacetamide Chemical compound CC(=O)N(C)CCN(C)C(C)=O TYJXKGNJOSVQCP-UHFFFAOYSA-N 0.000 claims description 2
- 235000017550 sodium carbonate Nutrition 0.000 claims description 2
- HLBBKKJFGFRGMU-UHFFFAOYSA-M sodium formate Chemical compound [Na+].[O-]C=O HLBBKKJFGFRGMU-UHFFFAOYSA-M 0.000 claims description 2
- 235000019254 sodium formate Nutrition 0.000 claims description 2
- JXKPEJDQGNYQSM-UHFFFAOYSA-M sodium propionate Chemical compound [Na+].CCC([O-])=O JXKPEJDQGNYQSM-UHFFFAOYSA-M 0.000 claims description 2
- 239000004324 sodium propionate Substances 0.000 claims description 2
- 235000010334 sodium propionate Nutrition 0.000 claims description 2
- 229960003212 sodium propionate Drugs 0.000 claims description 2
- 238000002347 injection Methods 0.000 abstract description 65
- 239000007924 injection Substances 0.000 abstract description 65
- 239000000693 micelle Substances 0.000 abstract description 16
- 238000011084 recovery Methods 0.000 abstract description 7
- 150000003839 salts Chemical class 0.000 abstract description 7
- 239000002253 acid Substances 0.000 abstract description 4
- 238000001879 gelation Methods 0.000 abstract description 4
- 150000001412 amines Chemical class 0.000 abstract description 2
- 230000002035 prolonged effect Effects 0.000 abstract description 2
- 238000002360 preparation method Methods 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 34
- 230000000694 effects Effects 0.000 description 13
- 239000006260 foam Substances 0.000 description 11
- 239000012530 fluid Substances 0.000 description 10
- 230000002265 prevention Effects 0.000 description 9
- 239000011435 rock Substances 0.000 description 9
- BVKZGUZCCUSVTD-UHFFFAOYSA-M Bicarbonate Chemical compound OC([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-M 0.000 description 8
- 239000000839 emulsion Substances 0.000 description 8
- 230000000087 stabilizing effect Effects 0.000 description 8
- 230000015572 biosynthetic process Effects 0.000 description 6
- 230000000903 blocking effect Effects 0.000 description 6
- 239000011159 matrix material Substances 0.000 description 6
- 239000010779 crude oil Substances 0.000 description 5
- 238000006073 displacement reaction Methods 0.000 description 5
- 239000007788 liquid Substances 0.000 description 5
- 238000007789 sealing Methods 0.000 description 5
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 4
- PIICEJLVQHRZGT-UHFFFAOYSA-N Ethylenediamine Chemical compound NCCN PIICEJLVQHRZGT-UHFFFAOYSA-N 0.000 description 4
- 229910052799 carbon Inorganic materials 0.000 description 4
- 238000009833 condensation Methods 0.000 description 4
- 230000005494 condensation Effects 0.000 description 4
- 238000010276 construction Methods 0.000 description 4
- 238000010438 heat treatment Methods 0.000 description 4
- 238000000034 method Methods 0.000 description 4
- 239000012466 permeate Substances 0.000 description 4
- 238000003756 stirring Methods 0.000 description 4
- 239000004568 cement Substances 0.000 description 3
- 238000004090 dissolution Methods 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 239000003292 glue Substances 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 238000006386 neutralization reaction Methods 0.000 description 2
- 239000002244 precipitate Substances 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- 238000001338 self-assembly Methods 0.000 description 2
- 230000009919 sequestration Effects 0.000 description 2
- GETQZCLCWQTVFV-UHFFFAOYSA-N trimethylamine Chemical compound CN(C)C GETQZCLCWQTVFV-UHFFFAOYSA-N 0.000 description 2
- 239000011800 void material Substances 0.000 description 2
- BRLQWZUYTZBJKN-UHFFFAOYSA-N Epichlorohydrin Chemical compound ClCC1CO1 BRLQWZUYTZBJKN-UHFFFAOYSA-N 0.000 description 1
- 239000004698 Polyethylene Substances 0.000 description 1
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Chemical compound NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 230000000996 additive effect Effects 0.000 description 1
- AZDRQVAHHNSJOQ-UHFFFAOYSA-N alumane Chemical class [AlH3] AZDRQVAHHNSJOQ-UHFFFAOYSA-N 0.000 description 1
- 239000008346 aqueous phase Substances 0.000 description 1
- 230000009172 bursting Effects 0.000 description 1
- 239000004202 carbamide Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000001934 delay Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000002349 favourable effect Effects 0.000 description 1
- 238000007654 immersion Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000008595 infiltration Effects 0.000 description 1
- 238000001764 infiltration Methods 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- IPGOVDXOBDFUBM-UHFFFAOYSA-N oxalic acid;sodium Chemical compound [Na].OC(=O)C(O)=O IPGOVDXOBDFUBM-UHFFFAOYSA-N 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229920000768 polyamine Polymers 0.000 description 1
- 229920000573 polyethylene Polymers 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 125000006850 spacer group Chemical group 0.000 description 1
- 230000007480 spreading Effects 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
-
- 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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
The invention provides a carbon dioxide flooding expansion wave and volume gel channeling inhibitor suitable for an ultralow permeability reservoir, which comprises the following components in percentage by weight: gemini type fatty tertiary amine: 1-3%, mono-alkyl tertiary fatty amine: 1-3%, alkyl amine oxide: 0.1-0.4%, and a sizing agent: 0.2-0.8%, retarder: 0.1-0.4%, and the balance being water. The channeling-preventing agent is mainly characterized in that fatty tertiary amine reacts with carbon dioxide at the stratum temperature to generate fatty alkyl bicarbonate, the fatty alkyl bicarbonate and a gelling agent are self-assembled to generate rod-shaped micelles, the micelles are mutually entangled to finally generate high-viscosity gel, the retarder can delay the generation of the rod-shaped micelles, the gelling time is prolonged, the injectability of the channeling-preventing agent in an ultralow permeability reservoir in the early stage of injection is improved, the channeling-preventing agent is good in salt resistance and acid resistance, low in initial viscosity and good in injectability, the preparation process is simple, the viscosity is high after gelation, the starting pressure and the stable pressure are obviously increased, the channeling of carbon dioxide can be effectively blocked in the ultralow permeability reservoir, the wave-over efficiency is obviously enlarged, and the carbon dioxide flooding recovery ratio is favorably improved.
Description
Technical Field
The invention belongs to the field of chemical oil displacement, relates to a gas-driven expanding sweep volume channeling-preventing agent, and particularly relates to an ultra-low permeability oil reservoir carbon dioxide-driven expanding sweep volume gel channeling-preventing agent and application thereof.
Background
In recent years, national strategies of carbon peak and carbon neutralization are proposed, and geological sequestration and utilization of carbon dioxide are effective ways for directly realizing carbon peak and carbon neutralization, and carbon dioxide flooding is adopted, so that sequestration of carbon dioxide can be effectively realized, and crude oil recovery efficiency can be further improved by utilizing the property of carbon dioxide. The carbon dioxide flooding is selected by the low permeability reservoir because compared with the high permeability reservoir, the carbon dioxide has reduced migration capacity in the low permeability reservoir, greatly delays the gas channeling time, prolongs the beginning of carbon dioxide injection of the low permeability reservoir in the oil field, and achieves a certain effect.
In practice, carbon dioxide flooding is adopted, and almost all gas is leaked in the carbon dioxide flooding process, so that the extent of expanding the swept volume of carbon dioxide is reduced, and the common channeling prevention technology is to thicken the viscosity of an aqueous phase after adding a chemical additive, so that the injection property of the ultra-low permeability oil reservoir is poor, the difficulty is higher than that of water injection displacement, deep channeling sealing is difficult to realize, and the final carbon dioxide flooding effect is poor.
There are also many oil fields in which an expanding agent is added to cement as an air channeling inhibitor, and there are chemical expansion, i.e., lattice expansion and gas expansion, and physical expansion, i.e., aerated cement. However, the two methods of injecting the expanding agent have the defects that the plugging matrix can generate uneven stress distribution, cracks can occur, and new channels can be generated to cause channeling. In addition, the strength of the plugging matrix is obviously reduced by the infiltration of the gas, in addition, the cement often generates permanent plugging, and the deep part of the stratum is difficult to effectively plug the carbon dioxide channeling. It is also described that the new channeling-preventing agent is synthesized by taking polyethylene polyamine, epichlorohydrin, trimethylamine and the like as raw materials, so that the resistance coefficient of the high permeable layer of the rock core is increased, the flow ratio of the high permeable layer to the low permeable layer is reduced, but the plugging capability is reduced after water immersion, and the channeling-preventing agent is not suitable for carbon dioxide flooding in the ultralow permeable oil reservoir. The invention patent ZL200710172367.4 'an anti-channeling agent for carbon dioxide flooding of an ultralow permeability reservoir and application thereof' prepares a carbon dioxide flooding gel anti-channeling agent, wherein the anti-channeling agent is prepared by reacting carbon dioxide with ethylenediamine to generate organic salt precipitate so as to block a gas channeling channel, and the addition of spacer fluid ethanol is effective in controlling time. However, the organic salt precipitate is easy to dissolve rapidly after the stratum water is immersed, so that the plugging effect is invalid. The invention patent ZL201310523013.2 'an air-driven channeling-preventing agent and an application method thereof' adopts inorganic gel prepared from inorganic aluminum salt, ethylenediamine, urea and the like, has the viscosity reaching 500mPa.s, finally generates salt precipitation, and has the conditions of poor stability and easy rapid dissolution when stratum water is immersed. Foam is also adopted to block carbon dioxide channeling, and the main reasons of the foam for profile control and oil displacement are that the seepage characteristics of the foam in a porous medium, namely the effects of large and small foam blocking and water and oil blocking, lead to uniform propulsion of the foam at high and low permeability. Meanwhile, the foam also has the capability of blocking gas channeling, so that the subsequent injected water or gas can enter the low-permeability layer, the purpose of adjusting the profile is achieved, the foam has a certain capability of blocking channeling, but the formation is too strong in heterogeneity and easy to cause gas to be bumped in. However, the high-strength foam needs to be added with a polymer with high molecular weight to enhance the thickness of the foam interface film, but the injection of the ultra-low permeability oil reservoir is difficult to meet, so that the injection and the efficient channeling prevention cannot be achieved. Some researchers also use gel foam to plug a carbon dioxide gas channeling well, so that a better plugging effect is generated, but the target position of the deep large crack and large hole of the stratum cannot be plugged aiming at the situation that whether the ultra-low permeability reservoir has poor injectability or is difficult to enter the large crack and large hole through the ultra-low permeability region. Therefore, the invention develops the channeling-preventing agent with initial viscosity as low as water aiming at the difficult problem of gas channeling of the carbon dioxide foam of the ultralow permeability reservoir, improves the injectability of the channeling-preventing agent, can move to the target position of the large crack and large hole of the stratum, has Hou Ningcheng glue, has high strength after glue formation and good acid and salt resistance, can realize the blocking of carbon dioxide and effectively control gas channeling.
Disclosure of Invention
The carbon dioxide gel-expelling channeling-preventing agent suitable for the ultralow permeability oil reservoir and the application thereof can be used for self-assembling to generate rod-shaped micelles, the micelles are mutually entangled, the viscosity is greatly increased, and finally, a fixed gel can be formed, the retarder can delay the generation of the rod-shaped micelles, the gel-forming time is prolonged, a time window is provided for site construction and underground migration of the channeling-preventing agent, the injectability in the ultralow permeability oil reservoir is improved, the penetrability is high, the channeling-preventing agent has good salt resistance and acid resistance, the initial viscosity is low, the intensity after gelation is high, the channeling of carbon dioxide gas can be blocked in the ultralow permeability oil reservoir, the sweep efficiency is remarkably enlarged, and the carbon dioxide oil displacement efficiency is improved.
The gel channeling-preventing agent suitable for expanding the spreading volume of the carbon dioxide flooding of the ultra-low permeability reservoir consists of the following components in percentage by weight:
gemini type fatty tertiary amine: 1 to 3 percent,
Mono-alkyl fatty tertiary amine: 1 to 3 percent,
Alkyl amine oxides: 0.1 to 0.4 percent,
Sizing agent: 0.2 to 0.8 percent,
Retarder: 0.1-1%,
The balance being water.
Preferably, the Gemini type fatty tertiary amine is any one or more of (N, N '-dimethyl-N, N' -diacetyl) ethylenediamine, (N, N '-dimethyl-N, N' -dioctadecyl) ethylenediamine and (N, N '-dimethyl-N, N' -dioctadecyl) ethylenediamine.
Preferably, the mono-alkyl tertiary fatty amine is any one or more of N, N-dimethyl hexadecylamine, N-dimethyl octadecylamine, N-dimethyl eicosylamine and N, N-dimethyl eicosylenediamine.
Preferably, the alkyl amine oxide is any one or more of octaalkyl dimethyl amine oxide, decaalkyl dimethyl amine oxide, dodecyl dimethyl amine oxide and tetradecyl dimethyl amine oxide.
Preferably, the gelling agent is any one of sodium salicylate or sodium dodecyl sulfate.
Preferably, the retarder is any one or more of sodium carbonate, sodium acetate, sodium formate, sodium propionate and sodium malonate.
As used herein, a "slug" is a well-known term of art that refers to a fluid injected into a porous medium of a subterranean formation that, prior to not fully diffusing, has a shape that approximates a section of the fluid moving in a plug-like manner in the pores.
As used herein, "PV" is a well-known term of art and refers to the void volume of a core, for example, injecting 1PV fluid or injecting fluid in a volume equal to the void volume of the core.
The extremely low permeability oil reservoir applied to the channeling-preventing agent disclosed by the invention has a permeability dividing standard which accords with the standard commonly adopted in the petroleum industry, namely, the permeability of the oil reservoir is generally lower than 0.1-10 multiplied by 10 -3um2.
The invention has the advantages that:
the invention provides a Gemini type fatty tertiary amine and a mono-alkyl fatty tertiary amine which react with carbon dioxide at formation temperature to generate fatty alkyl bicarbonate. But can slow down the formation of fatty alkyl bicarbonate under the action of retarder, thereby slowing down the self-assembly of fatty alkyl bicarbonate and gelling agent, generating rod-shaped micelle, and the rod-shaped micelle is mutually entangled to gel the system, so that the viscosity is obviously increased. Therefore, the purpose of the delay time is to provide a construction time window for the agent, when the channeling-preventing agent liquid encounters carbon dioxide at the formation channeling-preventing target position, the channeling-preventing agent liquid self-assembles to generate rod-shaped micelles, the rod-shaped micelles are mutually entangled at the channeling-preventing target position, the viscosity of the rod-shaped micelles is greatly increased by gelation, and the bursting of the carbon dioxide is effectively inhibited. The retarder can delay the generation of rod-shaped micelle, prolong the gel forming time, reduce the viscosity of a system in the injection process and improve the injectability in an ultra-low permeability reservoir. The channeling-preventing agent has the advantages of good salt resistance, acid resistance, low initial viscosity, high strength after gelation, capability of blocking carbon dioxide channeling in an ultralow permeability reservoir, remarkable expansion of sweep efficiency and contribution to improvement of carbon dioxide displacement efficiency.
When the invention generates the channeling of carbon dioxide gas, no isolating liquid is needed between the carbon dioxide injection and the channeling prevention, a certain amount of prepared channeling prevention liquid is directly injected after the carbon dioxide is injected to generate the channeling prevention liquid, then the carbon dioxide is injected, and the injection pressure of each stage is recorded under the same injection rate. The channeling-preventing agent is simple in construction and easy to operate in site construction. After the injection quantity enters the target position according to the design, the well is closed for 2-5 hours, namely the gel is gelled, so that the viscosity of the gel is obviously increased. The channeling-preventing agent can improve the water injection pressure of the subsequent carbon dioxide, improve the seepage capability of the mixed fluid, and is favorable for inhibiting the carbon dioxide from generating gas channeling, thereby improving the recovery ratio of the ultra-low permeability oil reservoir.
Detailed Description
Example 1
Firstly adding 95.2 g of common oil field stratum water, then adding 0.2 g of dodecyl dimethyl amine oxide, dissolving uniformly, then adding 3 g of Gemini type fatty tertiary amine (N, N '-dimethyl-N, N' -biseicosyl) ethylenediamine and 1 g of monoalkyl fatty tertiary amine N, N-dimethyl hexadecylamine, stirring and heating to 60 ℃ to obtain white emulsion, then sequentially adding 0.4 g Cheng Jiao g of sodium salicylate and 0.2 g of retarder sodium carbonate, and dissolving uniformly to obtain the carbon dioxide flooding expansion wave-volume gel channeling inhibitor.
The standard core of the ultra-low permeability oil reservoir is used for examining the channeling sealing effect of the channeling preventing agent after carbon dioxide injection is escaped. Under the condition of 60 ℃ of the oil reservoir temperature, water is injected into a rock core with the permeability of 1.7X10 -3μm2 at the injection rate of 0.1mL/min, the starting pressure and the stable pressure of the water injection are tested, then carbon dioxide gas is injected at the injection rate of 0.1mL/min, the starting pressure and the stable pressure of the injection when carbon dioxide escaping occurs at the outlet end are measured, then 1PV channeling-preventing agent emulsion is injected at the injection rate of 0.1mL/min, the curing is completed for 3 hours, so that the carbon dioxide gas remaining in the rock core fully permeates into the channeling-preventing agent, and tertiary amine groups fully react with carbon dioxide to generate Gemini alkyl bicarbonate and monoalkyl bicarbonate, and both the dialkyl bicarbonate and sodium salicylate can be self-assembled to form rod-shaped micelles to generate gel, so that the viscosity of the system is obviously increased. The initial viscosity of the channeling-preventing agent is low, the injectability of the ultra-low permeability reservoir is well met, and the channeling-preventing agent can effectively block carbon dioxide channeling when the viscosity of the channeling-preventing agent is increased at a target position. And finally, injecting carbon dioxide gas at an injection rate of 0.1mL/min, wherein a small amount of unreacted tertiary amine groups can still react with carbon dioxide entering the gel matrix, the viscosity of the system is further increased, the gel channeling prevention capacity is improved, and the starting pressure and the stable pressure of the carbon dioxide injected subsequently are measured. The channeling-preventing agent can improve the carbon dioxide gas channeling-preventing capability in the ultra-low permeability oil reservoir and the crude oil recovery ratio. The experimental results are shown in Table 1.
Table 1 fluid pressure variation for each slug injection
Experimental results show that the core with the permeability of 1.7X10 -3um2 is filled with water, the injection starting pressure and the stable pressure are high and reach 12.4MPa and 10.5MPa respectively. And then starting to inject carbon dioxide, wherein the starting pressure is 9.80MPa, and is reduced by 20.97% compared with the starting pressure of water injection, which means that the permeability of the carbon dioxide in the ultra-low permeability core is stronger than that of water, and when carbon dioxide gas escaping occurs at the outlet end, the stable pressure of injection is reduced to 3.20MPa, and is reduced by 69.74% compared with the water injection stage, which means that serious escaping occurs in the gas injection of the ultra-low permeability oil reservoir. And then starting to inject the channeling-preventing agent, wherein the stable pressure of injecting carbon dioxide is reduced by 25.12% compared with the stable pressure of injecting water. Carbon dioxide is injected after the weather condensation, the starting pressure and the stabilizing pressure are obviously and rapidly increased to 25.8MPa and 21.4MPa respectively, which are far higher than the starting pressure and the stabilizing pressure in the early water injection, and 108.06% and 103.81% respectively, which indicates that the channeling-preventing agent can effectively prevent carbon dioxide from channeling and generate a strong plugging effect.
Example 2
93.6 G of ordinary oil field stratum water is added, then 0.1 g of tetradecyl dimethyl amine oxide is added, the solution is uniform, then 2 g of Gemini type fatty tertiary amine (N, N '-dimethyl-N, N' -bi-hexadecyl) ethylenediamine and 3 g of mono-alkyl fatty tertiary amine N, N-dimethyl eicosediamine are added, stirring and heating are carried out to 60 ℃ to obtain white emulsion, then 0.9 g of gelling agent sodium dodecyl sulfate and 0.4 g of retarder sodium malonate are sequentially added, and after uniform dissolution, the carbon dioxide flooding expansion sweep volume gel channeling inhibitor is obtained.
The standard core of the ultra-low permeability oil reservoir is used for examining the channeling sealing effect of the channeling preventing agent after carbon dioxide injection is escaped. At the oil reservoir temperature of 80 ℃, water is injected into a rock core with the permeability of 4.8X10 -3μm2 at the injection rate of 0.1mL/min, the starting pressure and the stable pressure of the water injection are tested, then carbon dioxide gas is injected at the injection rate of 0.1mL/min, the starting pressure and the stable pressure of the injection when carbon dioxide escaping occurs at the outlet end are measured, then 1PV channeling-preventing agent emulsion is injected at the injection rate of 0.1mL/min, the curing is completed for 3 hours, so that the carbon dioxide gas remaining in the rock core fully permeates into the channeling-preventing agent, and tertiary amine groups fully react with carbon dioxide to generate chemical reaction, so that Gemini alkyl bicarbonate and monoalkyl bicarbonate can be formed by synergistic self-assembly of the dialkyl bicarbonate and sodium salicylate to form rod-shaped micelle, gel is generated, and the viscosity of the system is obviously increased. The initial viscosity of the channeling-preventing agent is low, the injectability of the ultra-low permeability reservoir is well met, and the channeling-preventing agent can effectively block carbon dioxide channeling when the viscosity of the channeling-preventing agent is increased at a target position. And finally, injecting carbon dioxide gas at an injection rate of 0.1mL/min, wherein a small amount of unreacted tertiary amine groups can still react with carbon dioxide entering the gel matrix, the viscosity of the system is further increased, the gel channeling prevention capacity is improved, and the starting pressure and the stable pressure of the carbon dioxide injected subsequently are measured. The channeling-preventing agent can improve the carbon dioxide gas channeling-preventing capability in the ultra-low permeability oil reservoir and the crude oil recovery ratio. The experimental results are shown in Table 2.
Table 2 fluid pressure variation for each slug injection
Experimental results show that the core with the permeability of 4.8X10 -3um2 is filled with water, the injection starting pressure and the stable pressure are very high and respectively reach 11.1MPa and 9.70MPa. And then starting to inject carbon dioxide, wherein the starting pressure is 7.60MPa, and is reduced by 31.53% compared with the starting pressure of water injection, which means that the permeability of the carbon dioxide in the ultra-low permeability core is stronger than that of water, and when the carbon dioxide gas at the outlet end escapes, the stable pressure of injection is reduced to 2.80MPa, and is reduced by 71.13% compared with the water injection stage, which means that the serious escape of the gas injection in the ultra-low permeability oil reservoir occurs. And then starting to inject the channeling-preventing agent, wherein the stable pressure of injecting carbon dioxide is reduced by 30.92% compared with the stable pressure of injecting water. Carbon dioxide is injected after the weather condensation, the starting pressure and the stabilizing pressure are obviously and rapidly increased to 20.5MPa and 18.4MPa respectively, which are far higher than the starting pressure and the stabilizing pressure in the early water injection, and 84.68% and 89.69% respectively, which indicates that the channeling-preventing agent can effectively prevent carbon dioxide from channeling and generate a strong plugging effect.
Example 3
92.7 G of ordinary oil field stratum water is added, then 0.2 g of octaalkyl dimethyl amine oxide is added, the mixture is uniformly dissolved, then 5g of Gemini type fatty tertiary amine (N, N '-dimethyl-N, N' -dioctadecyl) ethylenediamine and 1 g of mono-alkyl fatty tertiary amine N, N-dimethyl eicosylamine are added, stirring and heating are carried out to 60 ℃ to obtain white emulsion, then 0.8 g Cheng Jiao g sodium salicylate and 0.3 g retarder oxalic acid sodium are sequentially added, and the carbon dioxide flooding expansion swept volume gel channeling inhibitor is obtained after uniform dissolution.
The standard core of the ultra-low permeability oil reservoir is used for examining the channeling sealing effect of the channeling preventing agent after carbon dioxide injection is escaped. Under the condition of the reservoir temperature of 70 ℃, water is injected into a rock core with the permeability of 8.9X10 -3μm2 at the injection rate of 0.1mL/min, the starting pressure and the stable pressure of the water injection are tested, then carbon dioxide gas is injected at the injection rate of 0.1mL/min, the starting pressure and the stable pressure injected when carbon dioxide escaping occurs at the outlet end are measured, then 1PV channeling-preventing agent emulsion is injected at the injection rate of 0.1mL/min, the curing is completed for 3 hours, so that the carbon dioxide gas remaining in the rock core fully permeates into the channeling-preventing agent, and tertiary amine groups fully react with carbon dioxide to generate chemical reaction, and Gemini alkyl bicarbonate and monoalkyl bicarbonate, and both dialkyl bicarbonate and sodium salicylate can be cooperated and self-assembled to form rod-shaped micelles to generate gel, so that the viscosity of the system is obviously increased. The initial viscosity of the channeling-preventing agent is low, the injectability of the ultra-low permeability reservoir is well met, and the channeling-preventing agent can effectively block carbon dioxide channeling when the viscosity of the channeling-preventing agent is increased at a target position. And finally, injecting carbon dioxide gas at an injection rate of 0.1mL/min, wherein a small amount of unreacted tertiary amine groups can still react with carbon dioxide entering the gel matrix, the viscosity of the system is further increased, the gel channeling prevention capacity is improved, and the starting pressure and the stable pressure of the carbon dioxide injected subsequently are measured. The channeling-preventing agent can improve the carbon dioxide gas channeling-preventing capability in the ultra-low permeability oil reservoir and the crude oil recovery ratio. The experimental results are shown in Table 3.
TABLE 3 variation of fluid pressure injected into each slug
Experimental results show that the core with the permeability of 8.9X10 -3um2 is filled with water, the injection starting pressure and the stable pressure are very high and respectively reach 10.6MPa and 8.7MPa. And then starting to inject carbon dioxide, wherein the starting pressure is 7.70MPa, and is reduced by 27.33% compared with the starting pressure of water injection, which means that the permeability of the carbon dioxide in the ultra-low permeability core is stronger than that of water, and when carbon dioxide gas escaping occurs at the outlet end, the stable pressure of injection is reduced to 3.90MPa, and is reduced by 55.17% compared with the water injection stage, which means that serious escaping occurs in the gas injection of the ultra-low permeability oil reservoir. And then starting to inject the channeling-preventing agent, wherein the stable pressure of injecting carbon dioxide is reduced by 27.58% compared with the stable pressure of injecting water. Carbon dioxide is injected after the weather condensation, the starting pressure and the stabilizing pressure are obviously and rapidly increased to 21.9MPa and 17.6MPa respectively, which are far higher than the starting pressure and the stabilizing pressure in the early water injection, and 106.06% and 102.30% respectively, which indicates that the channeling-preventing agent can effectively prevent carbon dioxide from channeling and generate a strong plugging effect.
Example 4
Firstly adding 95.8 g of common oil field stratum water, then adding 0.15 g of decanyl dimethyl amine oxide, dissolving uniformly, then adding 2g of Gemini type fatty tertiary amine (N, N '-dimethyl-N, N' -bistwenty-dialkyl) ethylenediamine and 1g of mono-alkyl fatty tertiary amine N, N-dimethyl hexadecylamine, stirring and heating to 60 ℃ to obtain white emulsion, then sequentially adding 0.75 g of gelling agent sodium dodecyl sulfate and 0.2 g of retarder sodium acetate, and dissolving uniformly to obtain the carbon dioxide flooding expansion swept volume gel channeling inhibitor.
The standard core of the ultra-low permeability oil reservoir is used for examining the channeling sealing effect of the channeling preventing agent after carbon dioxide injection is escaped. At the reservoir temperature of 50 ℃, water is injected into a rock core with the permeability of 0.52 multiplied by 10 -3μm2 at the injection rate of 0.1mL/min, the starting pressure and the stable pressure of the water injection are tested, then carbon dioxide gas is injected at the injection rate of 0.1mL/min, the starting pressure and the stable pressure injected when carbon dioxide escaping occurs at the outlet end are measured, then 1PV channeling-preventing agent emulsion is injected at the injection rate of 0.1mL/min, the curing is completed for 3 hours, so that the carbon dioxide gas remaining in the rock core fully permeates into the channeling-preventing agent, and tertiary amine groups fully react with carbon dioxide to generate Gemini alkyl bicarbonate and monoalkyl bicarbonate, and both the dialkyl bicarbonate and sodium salicylate can be self-assembled to form a rod-shaped micelle to generate gel, so that the viscosity of the system is obviously increased. The initial viscosity of the channeling-preventing agent is low, the injectability of the ultra-low permeability reservoir is well met, and the channeling-preventing agent can effectively block carbon dioxide channeling when the viscosity of the channeling-preventing agent is increased at a target position. And finally, injecting carbon dioxide gas at an injection rate of 0.1mL/min, wherein a small amount of unreacted tertiary amine groups can still react with carbon dioxide entering the gel matrix, the viscosity of the system is further increased, the gel channeling prevention capacity is improved, and the starting pressure and the stable pressure of the carbon dioxide injected subsequently are measured. The channeling-preventing agent can improve the carbon dioxide gas channeling-preventing capability in the ultra-low permeability oil reservoir and the crude oil recovery ratio. The experimental results are shown in Table 4.
Table 4 fluid pressure variation for each slug injection
Experimental results show that the core with the permeability of 0.52 multiplied by 10 -3um2 is filled with water, and the injection starting pressure and the stable pressure are high and respectively reach 19.7MPa and 16.7MPa. And then starting to inject carbon dioxide, wherein the starting pressure is 14.7MPa, and is reduced by 25.38% compared with the starting pressure of water injection, which means that the permeability of the carbon dioxide in the ultra-low permeability core is stronger than that of water, and when carbon dioxide gas escaping occurs at the outlet end, the stable pressure of injection is reduced to 3.2MPa, and is reduced by 52.69% compared with the water injection stage, which means that serious escaping occurs in the gas injection of the ultra-low permeability oil reservoir. And then starting to inject the channeling-preventing agent, wherein the stable pressure of injecting carbon dioxide is reduced by 19.76% compared with the stable pressure of injecting water. Carbon dioxide is injected after the weather condensation, the starting pressure and the stabilizing pressure are obviously and rapidly increased to 36.2MPa and 30.1MPa respectively, which are far higher than the starting pressure and the stabilizing pressure during early water injection by 83.73% and 80.23% respectively, which indicates that the channeling-preventing agent can effectively prevent carbon dioxide from channeling and generate a strong plugging effect.
Claims (1)
1. The utility model provides a be fit for extremely low permeability reservoir carbon dioxide to drive and expand and sweep volume gel anti-channeling agent which characterized in that: the carbon dioxide flooding gel channeling-preventing agent comprises the following components in percentage by weight:
gemini type fatty tertiary amine: 1 to 3 percent,
Mono-alkyl fatty tertiary amine: 1 to 3 percent,
Alkyl amine oxides: 0.1 to 0.4 percent,
Sizing agent: 0.2 to 0.8 percent,
Retarder: 0.1 to 0.4 percent,
The balance being water;
(1) The Gemini type fatty tertiary amine is any one or more of (N, N '-dimethyl-N, N' -diacetyl) ethylenediamine, (N, N '-dimethyl-N, N' -dioctadecyl) ethylenediamine and (N, N '-dimethyl-N, N' -dioctadecyl) ethylenediamine;
(2) The mono-alkyl fatty tertiary amine is any one or more of N, N-dimethyl hexadecylamine, N-dimethyl octadecylamine, N-dimethyl eicosylamine and N, N-dimethyl eicosylenediamine;
(3) The alkyl amine oxide is any one or more of octaalkyl dimethyl amine oxide, decaalkyl dimethyl amine oxide, dodecyl dimethyl amine oxide and tetradecyl dimethyl amine oxide;
(4) The gelling agent is any one of sodium salicylate or sodium dodecyl sulfate;
(5) The retarder is any one or more of sodium carbonate, sodium acetate, sodium formate, sodium propionate and sodium malonate.
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