CN112852398B - High-temperature foam profile control agent for offshore heavy oil steam flooding and application thereof - Google Patents
High-temperature foam profile control agent for offshore heavy oil steam flooding and application thereof Download PDFInfo
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- 239000006260 foam Substances 0.000 title claims abstract description 96
- 239000003795 chemical substances by application Substances 0.000 title claims abstract description 37
- 238000010795 Steam Flooding Methods 0.000 title claims abstract description 29
- 239000000295 fuel oil Substances 0.000 title claims abstract description 24
- 239000004088 foaming agent Substances 0.000 claims abstract description 38
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 28
- 239000003381 stabilizer Substances 0.000 claims abstract description 19
- 239000011734 sodium Substances 0.000 claims abstract description 16
- 229910052708 sodium Inorganic materials 0.000 claims abstract description 16
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 claims abstract description 15
- 239000002105 nanoparticle Substances 0.000 claims abstract description 15
- 239000002736 nonionic surfactant Substances 0.000 claims abstract description 15
- 229940051841 polyoxyethylene ether Drugs 0.000 claims abstract description 14
- 229920000056 polyoxyethylene ether Polymers 0.000 claims abstract description 14
- 239000003945 anionic surfactant Substances 0.000 claims abstract description 13
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims abstract description 13
- 239000004711 α-olefin Substances 0.000 claims abstract description 13
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical group [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims abstract description 10
- 150000007942 carboxylates Chemical class 0.000 claims abstract description 8
- LGORLCOUTMVEAC-UHFFFAOYSA-M sodium;2-nonylphenolate Chemical group [Na+].CCCCCCCCCC1=CC=CC=C1[O-] LGORLCOUTMVEAC-UHFFFAOYSA-M 0.000 claims abstract description 8
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical group O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 claims description 19
- 238000003756 stirring Methods 0.000 claims description 19
- 239000000725 suspension Substances 0.000 claims description 10
- 239000002245 particle Substances 0.000 claims description 9
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 8
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 claims description 8
- 238000004519 manufacturing process Methods 0.000 claims description 5
- 229910000030 sodium bicarbonate Inorganic materials 0.000 claims description 4
- 235000017557 sodium bicarbonate Nutrition 0.000 claims description 4
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 4
- NVIFVTYDZMXWGX-UHFFFAOYSA-N sodium metaborate Chemical compound [Na+].[O-]B=O NVIFVTYDZMXWGX-UHFFFAOYSA-N 0.000 claims description 4
- 239000007924 injection Substances 0.000 abstract description 12
- 238000011084 recovery Methods 0.000 abstract description 12
- 238000006073 displacement reaction Methods 0.000 abstract description 9
- 230000000694 effects Effects 0.000 abstract description 6
- 230000005465 channeling Effects 0.000 abstract description 5
- 238000011161 development Methods 0.000 abstract description 4
- 239000004094 surface-active agent Substances 0.000 abstract description 3
- 238000010793 Steam injection (oil industry) Methods 0.000 abstract description 2
- 238000005187 foaming Methods 0.000 description 15
- 239000007788 liquid Substances 0.000 description 14
- 239000000243 solution Substances 0.000 description 13
- 238000002347 injection Methods 0.000 description 11
- 238000000034 method Methods 0.000 description 11
- 239000003921 oil Substances 0.000 description 11
- 230000000052 comparative effect Effects 0.000 description 10
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 238000002360 preparation method Methods 0.000 description 6
- 238000002474 experimental method Methods 0.000 description 5
- 239000003708 ampul Substances 0.000 description 4
- 239000000203 mixture Substances 0.000 description 4
- 230000035699 permeability Effects 0.000 description 4
- IGFHQQFPSIBGKE-UHFFFAOYSA-N Nonylphenol Natural products CCCCCCCCCC1=CC=C(O)C=C1 IGFHQQFPSIBGKE-UHFFFAOYSA-N 0.000 description 3
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 description 3
- 230000032683 aging Effects 0.000 description 3
- 239000013043 chemical agent Substances 0.000 description 3
- 150000001875 compounds Chemical class 0.000 description 3
- 230000018109 developmental process Effects 0.000 description 3
- 238000011049 filling Methods 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- SNQQPOLDUKLAAF-UHFFFAOYSA-N nonylphenol Chemical compound CCCCCCCCCC1=CC=CC=C1O SNQQPOLDUKLAAF-UHFFFAOYSA-N 0.000 description 3
- 238000001556 precipitation Methods 0.000 description 3
- 239000002994 raw material Substances 0.000 description 3
- 239000004576 sand Substances 0.000 description 3
- 229910052938 sodium sulfate Inorganic materials 0.000 description 3
- 235000011152 sodium sulphate Nutrition 0.000 description 3
- 238000005303 weighing Methods 0.000 description 3
- 150000001732 carboxylic acid derivatives Chemical class 0.000 description 2
- GVGUFUZHNYFZLC-UHFFFAOYSA-N dodecyl benzenesulfonate;sodium Chemical compound [Na].CCCCCCCCCCCCOS(=O)(=O)C1=CC=CC=C1 GVGUFUZHNYFZLC-UHFFFAOYSA-N 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 238000009472 formulation Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- 229920006395 saturated elastomer Polymers 0.000 description 2
- 229940080264 sodium dodecylbenzenesulfonate Drugs 0.000 description 2
- 230000000087 stabilizing effect Effects 0.000 description 2
- 239000004604 Blowing Agent Substances 0.000 description 1
- 239000004372 Polyvinyl alcohol Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000010790 dilution Methods 0.000 description 1
- 239000012895 dilution Substances 0.000 description 1
- 150000002191 fatty alcohols Chemical class 0.000 description 1
- 229910010272 inorganic material Inorganic materials 0.000 description 1
- 239000011147 inorganic material Substances 0.000 description 1
- 239000003446 ligand Substances 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 229920002451 polyvinyl alcohol Polymers 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 238000007789 sealing Methods 0.000 description 1
- 238000010008 shearing Methods 0.000 description 1
- -1 sodium carboxylate Chemical class 0.000 description 1
- 230000006641 stabilisation Effects 0.000 description 1
- 238000011105 stabilization Methods 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
Classifications
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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
- C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection
-
- 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
-
- 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
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- 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
-
- 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
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
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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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/10—Nanoparticle-containing well treatment fluids
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- Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Physics & Mathematics (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Excavating Of Shafts Or Tunnels (AREA)
- Emulsifying, Dispersing, Foam-Producing Or Wetting Agents (AREA)
Abstract
The invention discloses a high-temperature foam profile control agent for offshore heavy oil steam flooding and application thereof. The high-temperature foam profile control agent comprises the following components in percentage by mass: 0.5 to 1 percent of foaming agent; 1-2% of nano-particle foam stabilizer and 0.01-0.05% of interface synergist; the balance of water; the foaming agent is an anionic surfactant and an anionic-nonionic surfactant, and the mass ratio of the anionic surfactant to the anionic-nonionic surfactant is 1-3: 1; the anionic surfactant is long-carbon-chain alpha-olefin sodium sulfonate, and the length of a carbon chain of the surfactant is 20-24; the anionic-nonionic surfactant is sodium nonylphenol polyoxyethylene ether carboxylate. The high-temperature foam profile control system has good stability at the temperature of 300-350 ℃, the resistance factor can reach more than 35, the system can be used for steam flooding and injection, the problems of steam overtopping and steam channeling can be effectively solved, the sweep efficiency and the displacement efficiency of offshore heavy oil steam flooding can be greatly improved, and therefore the development effect of heavy oil steam flooding thermal recovery is improved.
Description
Technical Field
The invention relates to a high-temperature foam profile control agent for offshore heavy oil steam flooding and application thereof, belonging to the technical field of oilfield chemistry.
Background
Steam injection thermal recovery is a main mode for recovering thick oil at present, and when a thick oil thermal recovery block enters a multi-round huff and puff stage and is shifted to steam flooding, due to the influences of factors such as heterogeneity of strata, difference of fluidity ratio, steam overtopping and the like, the periodic oil yield is reduced, the oil-steam ratio is reduced, the water content is increased, and the economic benefit is deteriorated. Steam overtaking and steam channeling are the main causes of low longitudinal and transverse sweep efficiency of steam. Research and practice at home and abroad show that the high-temperature-resistant foam profile control agent can effectively solve the problems of steam overburden and steam channeling, and the sweep efficiency and the displacement efficiency of steam can be effectively improved by utilizing the characteristic of high steam oil washing efficiency along with the injection of nitrogen and the foaming agent into the steam, so that the development effect of thick oil steam thermal recovery is improved.
The foaming agent meeting the requirement of offshore heavy oil steam flooding accompanied injection needs to resist the temperature of 300-350 ℃, and simultaneously keeps good foaming performance, while the common foaming agent can not meet the requirement of high temperature resistance. Chinese patent CN107903886A discloses a high-temperature-resistant foaming agent for assisting steam flooding, wherein the foaming agents, namely polyacrylamide, polyvinyl alcohol and alkylolamide, in the foaming agent are difficult to resist the high temperature of more than 300 ℃, and the foaming agent has high use concentration and is not suitable for the requirement of steam flooding co-injection. Therefore, a high-temperature foam profile control system which can be applied to offshore heavy oil steam flooding with injection is needed to be provided so as to improve the steam flooding development effect of the offshore heavy oil reservoir.
Disclosure of Invention
The invention aims to provide a high-temperature foam profile control agent for offshore heavy oil steam flooding, the high-temperature foam profile control system has better stability at 300-350 ℃, the resistance factor can reach more than 35, the high-temperature foam profile control agent can be used for steam flooding, the problems of steam overtopping and steam channeling can be effectively solved, the sweep efficiency and the displacement efficiency of offshore heavy oil steam flooding can be greatly improved, and the development effect of heavy oil steam flooding thermal recovery is improved.
The high-temperature foam profile control agent for offshore heavy oil steam flooding provided by the invention comprises the following components in percentage by mass:
0.5 to 1 percent of foaming agent; 1-2% of nano-particle foam stabilizer and 0.01-0.05% of interface synergist; the balance being water.
The high-temperature foam profile control agent for offshore heavy oil steam flooding specifically comprises any one of the following components in percentage by mass 1) -5):
1) 0.5 to 1 percent of foaming agent; 1-2% of nano-particle foam stabilizer and 0.05% of interface synergist; the balance of water;
2) 0.5 to 0.8 percent of foaming agent; 1-1.5% of nano-particle foam stabilizer and 0.05% of interface synergist; the balance of water;
3) 0.5 percent of foaming agent; 1% of nano-particle foam stabilizer and 0.05% of interface synergist; the balance of water;
4) 0.8 percent of foaming agent; 1.5% of a nano-particle foam stabilizer and 0.05% of an interface synergist; the balance of water;
5) 1% of a foaming agent; 2% of a nano-particle foam stabilizer and 0.05% of an interface synergist; the balance being water.
In the foam profile control agent, the foaming agent can be an anionic surfactant and an anionic-nonionic surfactant, wherein the mass ratio of the anionic surfactant to the anionic-nonionic surfactant is 1-3: 1, preferably 1: 1. 2: 1 or 3: 1;
the anionic surfactant may be sodium long carbon chain alpha-olefin sulfonate (C)20～C24)；
The anionic-nonionic surfactant can be sodium nonylphenol polyoxyethylene ether carboxylate, and the molecular formula of the anionic-nonionic surfactant is shown as a formula (1);
in the formula (2), n is any integer of 10-20, preferably 10-15, 10-20, 15-20, 10, 15 or 20.
In the foam profile control agent, the nano-particle foam stabilizer is nano-modified bentonite, and the particle size is 100-300 nm.
In the foam profile control agent, the interface synergist can be at least one of sodium metaborate, sodium carbonate and sodium bicarbonate.
The invention also provides a preparation method of the foam profile control agent, which comprises the following steps:
s1, preparing a suspension of the nanoparticle foam stabilizer;
s2, adding the foaming agent and the interface synergist into the suspension, and stirring and dispersing to obtain the foam profile control and flooding agent.
In the preparation method, in step S1, the nanoparticle foam stabilizer is added into water, stirred for 1-2 hours under the condition of 1500-2000 r/min, and then kept stand for 8-12 hours.
In the preparation method, in step S2, the foaming agent and the interfacial synergist are added under a stirring condition of 100 to 200r/min, and the mixture is stirred and dispersed for 10 to 30min to obtain the foam profile control agent.
The offshore heavy oil high-temperature foam profile control and flooding system adopts a compound system of a temperature-resistant anionic surfactant and an anionic-nonionic surfactant as a foaming agent, and the compound systems of the anionic surfactant and the anionic-nonionic surfactant are closely arranged on a gas-liquid interface to form a compact interface film, so that the foaming agent solution not only has better foaming capacity and foam stability, but also has a synergistic effect of an added interface synergist and the compound surfactant, and can reduce the oil-water interface tension to 10-2mN·m-1The high-temperature foam profile control agent has good plugging and flooding capabilities, and can greatly improve the recovery ratio of steam foam flooding.
The offshore heavy oil high-temperature foam profile control and flooding system adopts inorganic nano modified bentonite as a foam stabilizer, can be adsorbed on a gas-liquid interface to strengthen the strength of a gas-liquid interface film, can form a three-dimensional network structure in a water phase, and improves the viscosity of a foam system liquid film, so that the stability and profile control and flooding capacity of foam can be greatly improved. Meanwhile, the nano modified bentonite is used as an inorganic material, has temperature resistance which is basically not influenced by temperature, and can meet the requirements of steam flooding and co-injection of different heavy oil reservoirs.
The offshore heavy oil high-temperature foam profile control and flooding system has shear dilution, is influenced by high shear rate in the injection process, reduces the viscosity of the system, is beneficial to injection, can recover the viscosity of the system after being injected into a stratum, and depends on the Jamin effect of foam, so that the sweep coefficient of steam can be greatly improved. The foam profile control and flooding agent overcomes the problems that the injection pressure is too high, the viscosity is reduced under the shearing action, the polymer is easy to degrade under high temperature and the like when the polymer is used as a foam stabilizer in the injection process.
The offshore heavy oil high-temperature foam profile control and flooding system has better foaming capacity and extremely high foam stability, and can greatly improve the recovery ratio of steam flooding. The foaming volume of the foam profile control system can reach 700mL, the half-life period of the solution to be separated is 132min, the half-life period of the foam is more than 30h, the foaming volume can reach 610mL after aging for 72h at the temperature of 320 ℃, the half-life period of the solution to be separated is 93min, and the half-life period of the foam is more than 26h, which are measured by a Waring Blender stirring method experiment at the room temperature of 25 ℃. With a permeability of about 3000X 10-3μm2The sandstone core can improve the recovery ratio by more than 20 percent on the basis of steam flooding, and is an efficient profile control and flooding system for thickened oil steam flooding.
Detailed Description
The experimental procedures used in the following examples are all conventional procedures unless otherwise specified.
Materials, reagents and the like used in the following examples are commercially available unless otherwise specified.
Examples 1,
The raw materials comprise the following components in percentage by mass:
1.0% of foaming agent, 2% of nano modified bentonite (the particle size is 100-300 nm), 0.05% of sodium metaborate and 96.95% of water;
wherein, it is startedThe foaming agent is long carbon chain alpha-olefin sodium sulfonate (C)20～C24) And sodium nonylphenol polyoxyethylene ether carboxylate APEC-10 (in formula (1), n ═ 10) in a mass ratio of 3: 1.
The preparation method comprises the following steps:
(1) weighing 2g of nano modified bentonite, slowly adding 96.95g of water under the stirring condition of 500r/min, increasing the rotating speed to 2000r/min, stirring for 2h, fully expanding and dispersing the nano modified bentonite to form a homogeneous suspension solution, and standing for 10h for later use.
(2) And (2) adding 1.0g of foaming agent and 0.05g of sodium metaborate into the nano modified bentonite particle suspension solution obtained in the step (1), and continuously stirring at the stirring speed of 100r/min for 30min to obtain the high-temperature foam profile control and flooding agent.
Examples 2,
The raw materials comprise the following components in percentage by mass:
0.8% of foaming agent, 1.5% of nano modified bentonite (the particle size is 100-300 nm), 0.05% of sodium carbonate and 97.65% of water;
wherein the foaming agent is long carbon chain alpha-olefin sodium sulfonate (C)20～C24) And sodium nonylphenol polyoxyethylene ether carboxylate APEC-15 (in formula (1), n ═ 15) in a mass ratio of 2: 1.
The preparation method comprises the following steps:
(1) weighing 1.5g of nano modified bentonite, slowly adding 97.65g of water under the stirring condition of 500r/min, increasing the rotating speed to 1500r/min, stirring for 2h, fully expanding and dispersing the nano modified bentonite to form a homogeneous suspension solution, and standing for 12h for later use.
(2) And (2) adding 0.8g of foaming agent and 0.05g of sodium carbonate into the suspension solution of the nano modified bentonite particles obtained in the step (1), and continuously stirring at the stirring speed of 150r/min for 20min to obtain the high-temperature foam profile control and flooding agent.
Examples 3,
The raw materials comprise the following components in percentage by mass:
0.5% of foaming agent, 1.0% of nano modified bentonite (the particle size is 100-300 nm), 0.05% of sodium bicarbonate and 98.45% of water;
wherein bubbles are formedThe agent is long carbon chain alpha-olefin sodium sulfonate (C)20～C24) And nonylphenol polyoxyethylene ether carboxylic acid sodium APEC-20 (in formula (1), n ═ 20) in a mass ratio of 1: 1.
The preparation method comprises the following steps:
(1) weighing 1.0g of nano modified bentonite, slowly adding 98.45g of water under the stirring condition of 500r/min, increasing the rotating speed to 1800r/min, stirring for 2h, fully expanding and dispersing the nano modified bentonite to form a homogeneous suspension solution, and standing for 8h for later use.
(2) And (2) adding 0.5g of foaming agent and 0.05g of sodium bicarbonate into the nano modified bentonite particle suspension solution obtained in the step (1), and continuously stirring at the stirring speed of 200r/min for 10min to obtain the high-temperature foam profile control and flooding agent.
Comparative examples 1,
The foaming agent is 1.0 percent of sodium dodecyl benzene sulfonate and sodium nonylphenol polyoxyethylene ether carboxylate APEC-15 according to the mass ratio of 3:1, the rest of the formulation is the same as that in example 1, and the foam profile control agent is prepared according to the method in example 1.
Comparative examples 2,
The foaming agent is 1.0 percent of long carbon chain alpha-olefin sodium sulfonate (C)20～C24) And fatty alcohol polyoxyethylene ether sodium sulfate AES according to the mass ratio of 3:1, the rest of the formulation is the same as that in example 1, and the foam profile control agent is prepared according to the method in example 1.
Comparative examples 3,
The foaming agent is 1.0 percent of long carbon chain alpha-olefin sodium sulfonate (C)20～C24) And nonylphenol polyoxyethylene ether carboxylic acid sodium APEC-15 according to the mass ratio of 3:1, 2% of nano modified bentonite (the particle size is 100-300 nm) and 97% of water; a foam profile control agent was prepared according to the method of example 1.
Example 4 foam Properties and high temperature stability of foam flooding Agents
Experimental sample (one): foam profile control agents prepared in examples 1-3.
(1) The foaming performance and foam stabilizing performance of the foam system are evaluated by adopting a Waring Blender stirring method, and the experiment comprises the following specific steps: 200mL of chemical agent solution with a certain concentration is prepared. 100mL of the prepared solution is poured into a stirrer, the stirrer is rotated at the rotating speed of 3000r/min for 60s to form uniform and stable foam, the generated foam is quickly poured into a 1000mL measuring cylinder, the volume of the generated foam is recorded, then the time required for half of the amount of the foam precipitation and half of the foam volume to decay is recorded, and the half-life period of the solution precipitation and the half-life period of the foam are recorded. The results are shown in Table 1.
(2) High temperature aging test: putting a chemical agent solution with a certain concentration into an ampoule bottle, sealing the ampoule bottle, putting the ampoule bottle into a high-temperature tank, placing the ampoule bottle into a high-temperature oven at 320 ℃ for heat treatment for 72 hours, and measuring the foaming volume, the liquid precipitation half-life period and the foam half-life period of the heat-treated chemical agent by adopting a Waring Blender method. The results are shown in Table 1.
TABLE 1 foam properties and high temperature stability of the systems prepared in examples 1-3 and comparative examples
As can be seen from the data in Table 1, in comparative example 1, sodium dodecylbenzene sulfonate and sodium nonylphenol polyoxyethylene ether carboxylate are used as foaming agents, although the foaming performance is not changed greatly after heat treatment, the foaming capacity is obviously inferior to that of the long carbon chain sodium alpha-olefin sulfonate compounded surfactant foaming system. In the comparative example 2, the long-carbon-chain alpha-olefin sodium sulfonate and the fatty alcohol-polyoxyethylene ether sodium sulfate AES are used as foaming agents, the foaming performance of the system is good at room temperature, but the foaming performance is greatly reduced after heat treatment, which indicates that the fatty alcohol-polyoxyethylene ether sodium sulfate AES has poor temperature resistance. The foaming agent is a complex system of long-carbon-chain alpha-olefin sodium sulfonate anionic surfactant and sodium nonylphenol polyoxyethylene ether carboxylate anion-nonionic surfactant, and complex ligand systems of the anionic surfactant and the anion-nonionic surfactant are closely arranged on a gas-liquid interface to form a compact interface film, so that the foaming system has better foaming performance. Meanwhile, inorganic nano modified bentonite is used as a foam stabilizer, the temperature resistance is basically not influenced by temperature, the strength of a gas-liquid interfacial film is further enhanced, the viscosity of a foam liquid film can be obviously improved, the liquid discharge speed of the foam liquid film is greatly reduced, the foam stabilizing performance of a foam system under the high-temperature condition is greatly improved, and the requirements of steam flooding, profile control and flooding of heavy oil reservoirs at different temperatures are met.
Example 5 plugging and flooding Properties of foam flooding agent
The high-temperature foam profile control and flooding system prepared in the embodiment 1-3 and the comparative examples 1 and 2 are taken as research objects, and the profile control and flooding capacity of the high-temperature foam profile control and flooding system provided by the invention is examined. Adopts a material with the inner diameter of 25mm, the length of 300mm and the permeability of 3.00 mu m2And (4) performing foam plugging and oil displacement performance evaluation on the left and right sand filling pipe models.
The experimental flow of plugging performance evaluation is as follows: (1) firstly, saturating a sand filling pipe with water, and measuring the water phase permeability of a rock core; (2) and simultaneously injecting nitrogen and steam into the core according to the gas-liquid ratio of 1: 1. And when the pressure difference at the two ends of the core is stable, recording the pressure difference at the two ends of the core at the moment as the foundation pressure difference. (3) According to the same gas-liquid ratio of 1:1 simultaneously injecting nitrogen and a high-temperature foam system into the core. And when the pressure difference at the two ends of the core is stable, recording the pressure difference at the two ends of the core at the moment as the working pressure difference. And finally according to the formula: frThe resistance factor of the foam system was calculated as working differential pressure/base differential pressure.
The viscosity of the thick oil adopted in the experiment is 5862mPa & s at 50 ℃, and the experimental flow for evaluating the oil displacement performance is as follows: (1) after the sand filling pipe is saturated with water, measuring the equilibrium pressure, and calculating the permeability according to a Darcy formula; (2) after the crude oil is saturated, aging is carried out for 24 hours at 50 ℃; (3) injecting steam at 320 ℃, stopping displacement when the water content reaches 98%, and calculating the steam displacement recovery ratio; (4) injecting a 0.5PV high-temperature foam system; (5) and injecting the mixture again at 320 ℃ for subsequent steam flooding, finishing the flooding when the water content of the produced liquid is more than 98%, and calculating the final recovery ratio. The results are shown in Table 2. And recording the oil production and the water production in the whole displacement process, and calculating the recovery ratio of different stages. In the displacement process, the back pressure is set to be 10.0MPa, the temperature is 320 ℃, and the injection gas-liquid ratio is 1:1, the injection rate was 2.0 ml/min.
The results of the experiment are shown in table 2.
TABLE 2 Properties and flooding Effect of the foam profile control and flooding agents prepared in examples 1-3 and comparative examples 1-3
As can be seen from the data in Table 2, comparative example 3 uses the blowing agent as sodium long carbon chain alpha olefin sulfonate (C)20～C24) And nonylphenol polyoxyethylene ether sodium carboxylate APEC-15 according to the mass ratio of 3:1, and the foam stabilizer is nano modified bentonite. Although the foam profile control agent formed in the comparative example 3 has better plugging performance, the oil-water interfacial tension cannot be reduced to 10 due to no addition of the interfacial synergist-2mN·m-1And the recovery rate is smaller than that of the foam profile control and flooding system. The offshore heavy oil high-temperature foam system provided by the invention has strong high-temperature foaming capacity and long stabilization time, and the resistance factor can reach more than 35, so that the offshore heavy oil high-temperature foam system has very good high-temperature plugging performance, can effectively prevent the problems of steam overtopping and steam channeling, and improves the longitudinal and transverse sweep efficiency of steam flooding. Meanwhile, the foam system can reduce the oil-water interfacial tension to 10-2mN·m-1The high-temperature foam system is an efficient profile control and flooding system for the steam flooding of the thickened oil.
Claims (6)
1. A high-temperature foam profile control agent for offshore heavy oil steam flooding comprises the following components in percentage by mass:
0.5 to 1 percent of foaming agent; 1-2% of nano-particle foam stabilizer and 0.01-0.05% of interface synergist; the balance of water;
the foaming agent is an anionic surfactant and an anionic-nonionic surfactant, and the mass ratio of the anionic surfactant to the anionic-nonionic surfactant is 1-3: 1;
the anionic surfactant is long-carbon-chain alpha-olefin sodium sulfonate, and the length of a carbon chain of the long-carbon-chain alpha-olefin sodium sulfonate is 20-24;
the anionic-nonionic surfactant is sodium nonylphenol polyoxyethylene ether carboxylate, and the molecular formula of the anionic-nonionic surfactant is shown as a formula (1);
in the formula (1), n is any integer of 10-20;
the interfacial synergist is at least one of sodium metaborate, sodium carbonate and sodium bicarbonate.
2. The foam profile control agent according to claim 1, wherein: the nano-particle foam stabilizer is nano-modified bentonite, and the particle size of the nano-particle foam stabilizer is 100-300 nm.
3. A process for preparing a foam profile control agent as claimed in claim 1 or 2, comprising the steps of:
s1, preparing a suspension of the nanoparticle foam stabilizer;
and S2, adding the foaming agent and the interface synergist into the suspension, and stirring and dispersing to obtain the foam profile control and flooding agent.
4. The production method according to claim 3, characterized in that: in the step S1, the nanoparticle foam stabilizer is added into water, stirred for 1-2 hours under the condition of 1500-2000 r/min, and then kept stand for 8-12 hours.
5. The production method according to claim 3 or 4, characterized in that: in the step S2, the foaming agent and the interface synergist are added under the stirring condition of 100-300 r/min, and the foam profile control agent is obtained after stirring and dispersing for 10-30 min.
6. The foam profile control agent of claim 1 or 2 is applied to serve as a profile control agent for offshore heavy oil reservoir steam flooding.
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