CN114539996A - High-temperature-resistant long-acting channeling sealing agent and preparation method and application thereof - Google Patents
High-temperature-resistant long-acting channeling sealing agent and preparation method and application thereof Download PDFInfo
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- 230000005465 channeling Effects 0.000 title claims abstract description 116
- 238000007789 sealing Methods 0.000 title claims abstract description 103
- 238000002360 preparation method Methods 0.000 title abstract description 14
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 95
- WEVYAHXRMPXWCK-UHFFFAOYSA-N Acetonitrile Chemical compound CC#N WEVYAHXRMPXWCK-UHFFFAOYSA-N 0.000 claims abstract description 42
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 claims abstract description 28
- 239000011734 sodium Substances 0.000 claims abstract description 22
- 229910052708 sodium Inorganic materials 0.000 claims abstract description 22
- 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 20
- 239000002994 raw material Substances 0.000 claims abstract description 18
- FAGUFWYHJQFNRV-UHFFFAOYSA-N tetraethylenepentamine Chemical compound NCCNCCNCCNCCN FAGUFWYHJQFNRV-UHFFFAOYSA-N 0.000 claims abstract description 17
- 239000002893 slag Substances 0.000 claims abstract description 15
- AEQDJSLRWYMAQI-UHFFFAOYSA-N 2,3,9,10-tetramethoxy-6,8,13,13a-tetrahydro-5H-isoquinolino[2,1-b]isoquinoline Chemical compound C1CN2CC(C(=C(OC)C=C3)OC)=C3CC2C2=C1C=C(OC)C(OC)=C2 AEQDJSLRWYMAQI-UHFFFAOYSA-N 0.000 claims abstract description 14
- JBIROUFYLSSYDX-UHFFFAOYSA-M benzododecinium chloride Chemical compound [Cl-].CCCCCCCCCCCC[N+](C)(C)CC1=CC=CC=C1 JBIROUFYLSSYDX-UHFFFAOYSA-M 0.000 claims abstract description 14
- 229910000019 calcium carbonate Inorganic materials 0.000 claims abstract description 14
- 229940051841 polyoxyethylene ether Drugs 0.000 claims abstract description 14
- 229920000056 polyoxyethylene ether Polymers 0.000 claims abstract description 14
- 239000000176 sodium gluconate Substances 0.000 claims abstract description 14
- 229940005574 sodium gluconate Drugs 0.000 claims abstract description 14
- 235000012207 sodium gluconate Nutrition 0.000 claims abstract description 14
- DDAQLPYLBPPPRV-UHFFFAOYSA-N [4-(hydroxymethyl)-2-oxo-1,3,2lambda5-dioxaphosphetan-2-yl] dihydrogen phosphate Chemical compound OCC1OP(=O)(OP(O)(O)=O)O1 DDAQLPYLBPPPRV-UHFFFAOYSA-N 0.000 claims abstract description 11
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 9
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 claims abstract description 8
- VORRFUUQXVSQOQ-UHFFFAOYSA-N naphthalen-1-ylsulfonyloxymethyl naphthalene-1-sulfonate Chemical compound C1=CC=C2C(S(=O)(OCOS(=O)(=O)C=3C4=CC=CC=C4C=CC=3)=O)=CC=CC2=C1 VORRFUUQXVSQOQ-UHFFFAOYSA-N 0.000 claims abstract description 3
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 10
- 239000011259 mixed solution Substances 0.000 claims description 8
- 238000000034 method Methods 0.000 claims description 7
- PTLXXCCTGURQMN-UHFFFAOYSA-N CC1OP(O)(=O)OP(=O)(OO)O1 Chemical compound CC1OP(O)(=O)OP(=O)(OO)O1 PTLXXCCTGURQMN-UHFFFAOYSA-N 0.000 claims description 6
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 claims description 6
- 238000002156 mixing Methods 0.000 claims description 6
- 239000010865 sewage Substances 0.000 claims description 6
- 229910052938 sodium sulfate Inorganic materials 0.000 claims description 6
- 235000011152 sodium sulphate Nutrition 0.000 claims description 6
- 238000004519 manufacturing process Methods 0.000 abstract description 15
- 230000035699 permeability Effects 0.000 description 11
- 238000010276 construction Methods 0.000 description 9
- 230000032683 aging Effects 0.000 description 8
- 238000002474 experimental method Methods 0.000 description 8
- 230000035484 reaction time Effects 0.000 description 8
- 238000003756 stirring Methods 0.000 description 8
- 239000011435 rock Substances 0.000 description 6
- 238000002347 injection Methods 0.000 description 5
- 239000007924 injection Substances 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 4
- 239000002981 blocking agent Substances 0.000 description 4
- 238000011156 evaluation Methods 0.000 description 4
- 239000007788 liquid Substances 0.000 description 4
- 230000002035 prolonged effect Effects 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- 230000000903 blocking effect Effects 0.000 description 3
- 230000015271 coagulation Effects 0.000 description 3
- 238000005345 coagulation Methods 0.000 description 3
- 239000003814 drug Substances 0.000 description 3
- 230000000694 effects Effects 0.000 description 3
- 238000010521 absorption reaction Methods 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 238000010835 comparative analysis Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000002431 foraging effect Effects 0.000 description 2
- 238000011056 performance test Methods 0.000 description 2
- -1 sodium fatty alcohol Chemical class 0.000 description 2
- 238000010793 Steam injection (oil industry) Methods 0.000 description 1
- 239000000853 adhesive Substances 0.000 description 1
- 230000001070 adhesive effect Effects 0.000 description 1
- 230000002411 adverse Effects 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000011049 filling Methods 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 238000007711 solidification Methods 0.000 description 1
- 230000008023 solidification Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000003381 stabilizer Substances 0.000 description 1
- 239000000725 suspension Substances 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
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
- C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
- C09K8/493—Additives for reducing or preventing gas migration
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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
- C09K8/584—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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- 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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/243—Combustion in situ
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02W—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO WASTEWATER TREATMENT OR WASTE MANAGEMENT
- Y02W30/00—Technologies for solid waste management
- Y02W30/50—Reuse, recycling or recovery technologies
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Abstract
The invention provides a high-temperature-resistant long-acting channeling sealing agent, and a preparation method and application thereof. The raw materials for preparing the channeling sealing agent comprise the following components in percentage by mass: 4-8% of blast furnace slag, 0.5-1.5% of sodium fatty alcohol-polyoxyethylene ether sulfate, 0.3-0.7% of hydroxyethylidene diphosphate, 0.5-2% of calcium carbonate, 0.02-0.06% of acetonitrile, 0.02-0.07% of sodium beta-methylene dinaphthalene sulfonate, 0.01-0.05% of tetraethylenepentamine, 0.006-0.018% of dodecyl dimethyl benzyl ammonium chloride, 0.008-0.015% of sodium gluconate and the balance of water. The channeling sealing agent can effectively seal deep gas channeling channels of a stratum, has small damage to a non-gas channeling layer, realizes channeling sealing of any gas producing layer of a fireflood production well, and meets the requirement of fireflood oil reservoir high-temperature layered channeling sealing.
Description
Technical Field
The invention belongs to the technical field of oil extraction, and particularly relates to a high-temperature-resistant long-acting channeling sealing agent, and a preparation method and application thereof.
Background
Fire flooding is one of important core technologies for stable production and conversion development of Liaohe oil field, and 188 fire flooding well groups have been converted in blocks of 66 blocks, 3618 blocks and 3 blocks at present, and 47 ten thousand tons of annual oil production occurs. Due to the heterogeneity of the reservoir, the problems of uneven air suction, air channeling and the like in Liaohe fireflood development are serious. The existing fire flooding production well usually adopts a cage seal channeling technology to reduce the permeability and the tail gas quantity of a gas production layer, and simultaneously seals a non-gas channeling layer, thereby influencing the productivity of the oil well. The high-temperature-resistant long-acting plugging agent for the fireflood production well is limited by stratum voidage and injection of the particle plugging agent, and cannot be matched with sand filling and a packer to seal channeling in a layering way, so that the production problems of serious fireflood oil reservoir gas channeling and large tail gas quantity are solved.
Disclosure of Invention
The invention aims to provide a high-temperature-resistant long-acting channeling sealing agent suitable for a fireflood production well, which can effectively seal a deep gas channeling channel of a stratum, has small damage to a non-gas channeling layer, realizes channeling sealing of any gas production layer of the fireflood production well, and meets the requirements of high-temperature layered channeling sealing of a fireflood reservoir.
In order to achieve the purpose, the invention provides a high-temperature-resistant long-acting channeling sealing agent, wherein the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent comprise, by mass:
4-8% of blast furnace slag, 0.5-1.5% of sodium fatty alcohol-polyoxyethylene ether sulfate, 0.3-0.7% of hydroxyethylidene diphosphate, 0.5-2% of calcium carbonate, 0.02-0.06% of acetonitrile, 0.02-0.07% of sodium beta-methylene dinaphthalene sulfonate, 0.01-0.05% of tetraethylenepentamine, 0.006-0.018% of dodecyl dimethyl benzyl ammonium chloride, 0.008-0.015% of sodium gluconate and the balance of water.
In the high-temperature-resistant long-acting channeling sealing agent, the addition of the sodium fatty alcohol-polyoxyethylene ether sulfate effectively improves the viscosity of the high-temperature-resistant long-acting channeling sealing agent and improves the performance of the high-temperature-resistant long-acting channeling sealing agent; the addition of the hydroxyl ethylidene diphosphate can effectively improve the suspension dispersibility of each component in the high-temperature-resistant long-acting channeling sealing agent containing blast furnace slag; the calcium carbonate is matched with blast furnace slag, so that the blocking strength of the high-temperature-resistant long-acting channeling sealing agent is effectively improved, and the effective period of the measures of the high-temperature-resistant long-acting channeling sealing agent is prolonged; the addition of the acetonitrile can effectively improve the mutual solubility of the components in the high-temperature-resistant long-acting channeling sealing agent, so that the components can be well matched with each other to improve the utilization rate of the medicament of each component; the beta-methylene dinaphthalene sodium sulfonate mainly plays a role in solidification and forms a high-temperature-resistant long-acting channeling sealing agent after reacting with other components; the tetraethylenepentamine is used as an adhesive, so that the full reaction of all components is promoted, the plugging performance of the medicament is improved, and the effective period is prolonged; dodecyl dimethyl benzyl ammonium chloride is used as a stabilizer, so that the stability of the medicament formula is improved, and long-term effectiveness after curing is ensured; the sodium gluconate is used as a retarder to delay the curing time, prevent the flash coagulation phenomenon and ensure the safe injection in construction. In the high-temperature-resistant long-acting channeling sealing agent, the proportion of the blast furnace slag is preferably 5.5-8% based on 100% of the total mass of raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent.
In the high-temperature-resistant long-acting channeling sealing agent, the ratio of the fatty alcohol-polyoxyethylene ether sodium sulfate is preferably 0.6-1% by taking the total mass of raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent as 100%.
In the high-temperature-resistant long-acting channeling sealing agent, the percentage of the hydroxyethylidene diphosphate is preferably 0.35-0.5% based on 100% of the total mass of the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent.
In the high-temperature-resistant long-acting channeling sealing agent, the calcium carbonate accounts for 0.8-1.5% of the total mass of the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent, which is preferably 100%.
In the high-temperature-resistant long-acting channeling sealing agent, the proportion of the acetonitrile is preferably 0.03-0.04% based on 100% of the total mass of raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent.
In the high-temperature-resistant long-acting channeling sealing agent, the proportion of the sodium beta-methylenedinaphthalene sulfonate is preferably 0.04-0.045% by weight of the total mass of raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent being 100%.
In the high-temperature-resistant long-acting channeling sealing agent, the proportion of the tetraethylenepentamine is preferably 0.025-0.035% based on 100% of the total mass of the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent.
In the high-temperature-resistant long-acting channeling sealing agent, the proportion of the dodecyl dimethyl benzyl ammonium chloride is preferably 0.009-0.015% based on 100% of the total mass of raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent.
In the high-temperature-resistant long-acting channeling sealing agent, the ratio of the sodium gluconate to the total mass of the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent is preferably 0.01-0.012%.
In the high-temperature-resistant long-acting channeling sealing agent, the water is preferably oilfield reinjection sewage.
The invention also provides a preparation method of the high-temperature-resistant long-acting channeling sealing agent, which comprises the following steps:
mixing the blast furnace slag, fatty alcohol-polyoxyethylene ether sodium sulfate, hydroxyl ethylidene diphosphate, calcium carbonate, acetonitrile and water to obtain a mixed solution;
and mixing the mixed solution with the beta-methylene dinaphthalene sodium sulfonate, tetraethylenepentamine, dodecyl dimethyl benzyl ammonium chloride and sodium gluconate to obtain the high-temperature-resistant long-acting channeling sealing agent.
In the above preparation method, preferably, mixing the blast furnace slag, sodium fatty alcohol-polyoxyethylene ether sulfate, hydroxyethylidene diphosphate, calcium carbonate, acetonitrile and water to obtain a mixed solution is performed by: and sequentially adding the blast furnace slag, the fatty alcohol-polyoxyethylene ether sodium sulfate, the hydroxyl ethylidene diphosphate, the calcium carbonate and the acetonitrile into the water, and stirring at normal temperature to obtain the mixed solution. In one embodiment, the stirring time is 20-30 min.
In the preparation method, preferably, the mixing of the mixed solution with the sodium beta-methylenedinaphthalene sulfonate, tetraethylenepentamine, dodecyl dimethyl benzyl ammonium chloride and sodium gluconate to obtain the high-temperature-resistant long-acting channeling sealing agent is realized by the following steps: and sequentially adding the beta-methylene dinaphthalene sodium sulfonate, tetraethylenepentamine, dodecyl dimethyl benzyl ammonium chloride and sodium gluconate into the mixed solution, and stirring at normal temperature to obtain the high-temperature-resistant long-acting channeling sealing agent. In a specific embodiment, stirring is carried out for 10-20 min.
The invention also provides application of the high-temperature-resistant long-acting channeling sealing agent in deep channeling sealing of a fire flooding oil reservoir at the temperature of more than 350 ℃.
The high-temperature-resistant long-acting channeling sealing agent provided by the invention has the advantages of easily available raw materials, simple and convenient preparation method, good temperature resistance, controllable crosslinking time and long validity period, can realize deep long-distance channeling sealing in a stratum, effectively blocks a deep gas channeling channel in the stratum, has small damage to a non-gas channeling layer and realizes deep channeling sealing of a fireflood reservoir.
Detailed Description
The technical solutions of the present invention will be described in detail below in order to clearly understand the technical features, objects, and advantages of the present invention, but the present invention is not limited to the practical scope of the present invention.
Example 1
The embodiment provides a high-temperature-resistant long-acting channeling sealing agent, and the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent comprise, by mass:
5.5% blast furnace slag;
0.6% sodium fatty alcohol polyoxyethylene ether sulfate;
0.35% hydroxyethylidene diphosphate;
0.8% calcium carbonate;
0.03% acetonitrile;
0.04% sodium beta-methylenedinaphthalene sulfonate;
0.025% tetraethylenepentamine;
0.009% dodecyl dimethyl benzyl ammonium chloride;
0.01% sodium gluconate;
the balance is oil field reinjection sewage.
The preparation process comprises the following steps:
(1) sequentially adding blast furnace slag, fatty alcohol-polyoxyethylene ether sodium sulfate, hydroxyl ethylidene diphosphate, calcium carbonate and acetonitrile components into a liquid preparation tank containing a proper amount of reinjection sewage, and stirring for 20 minutes at normal temperature;
(2) and then, continuously and sequentially adding the components of the beta-methylene dinaphthalene sodium sulfonate, the tetraethylenepentamine, the dodecyl dimethyl benzyl ammonium chloride and the sodium gluconate into the liquid preparation tank, and stirring for 16 minutes at normal temperature to obtain the high-temperature-resistant long-acting channeling sealing agent.
Performance test 1
The high temperature resistant long acting channeling sealing agent provided in example 1 was tested for curing time, flowability, selective plugging and temperature resistance, respectively.
(1) Curing reaction time
In order to verify the controllability of the curing time of the high-temperature-resistant long-acting channeling sealing agent, a curing time measuring experiment is carried out, and as can be seen from the experimental data in table 1, the curing reaction time of the high-temperature-resistant long-acting channeling sealing agent is prolonged to be controllable within 3.5-7.5 days, so that the flash coagulation phenomenon is effectively prevented, and different formulas can be selected according to the requirements of the temperature of a field well during construction.
TABLE 1
| Temperature/. degree.C | 150 | 180 | 220 | 260 | 300 | 350 |
| Curing time/day | 7.5 | 6.9 | 6.2 | 5.3 | 4.8 | 3.5 |
(2) Fluidity test
At room temperature (20-25 ℃), 5 samples of the high-temperature-resistant long-acting channeling sealing agent provided in example 1 are tested by a rotary viscometer for viscosity value under the temperature condition, and the viscosity value reflects the rheological property, namely the pumpability, of the high-temperature-resistant long-acting channeling sealing agent under the condition. The experimental results in Table 2 show that the viscosity of the high-temperature-resistant long-acting channeling sealing agent is 143-168mPa & s at normal temperature, the pumpability meets the requirement, and the safe injection in the construction process can be ensured.
TABLE 2
(3) Selective plugging experiment
And (3) introducing high-temperature-resistant long-acting channeling sealing agents into the rock cores with different permeability level differences by adopting a double-pipe parallel model, and testing the starting pressure and the flow splitting rate.
TABLE 3
The experimental results in table 3 show that the larger the permeability level difference is, the larger the differential flow rate of the high-low permeability sand-packed pipe is, which indicates that the stronger the formation heterogeneity is, the stronger the flow-dividing ability of the high-temperature-resistant long-acting channeling-blocking agent is, and the more easily the high-temperature-resistant long-acting channeling-blocking agent enters the high-permeability part of the formation under the same condition, so that the low-permeability layer is not blocked.
(4) Evaluation of temperature resistance
The temperature resistance of the high-temperature-resistant long-acting channeling sealing agent provided in example 1 is tested by the specific method comprising the following steps: the high-temperature-resistant long-acting channeling sealing agent provided in example 1 is injected into a rock core, and the original permeability of the rock core is 3.02 mu m2Injecting a 2PV high-temperature channeling sealing agent, putting the core into a 350 ℃ oven for aging, and measuring the residual resistance coefficient of the core after different aging times, wherein the results are shown in a table 4. As can be seen from Table 4, after aging for 180d, the residual resistance coefficient of the core is still kept above 15, and the core shows better high-temperature plugging capability.
TABLE 4
(5) Comparative analysis experiment
Under the premise that other components of the high-temperature-resistant long-acting channeling sealing agent provided in example 1 are not changed, a hydroxyethylidene diphosphate component is removed to obtain a high-temperature-resistant long-acting channeling sealing agent II, the curing reaction time and the temperature resistance of the high-temperature-resistant long-acting channeling sealing agent II are tested, the experimental method is the same as the evaluation of the curing reaction time (1) and the temperature resistance (4) in example 1, and the results are shown in tables 5 and 6.
TABLE 5
| Temperature/. degree.C | 150 | 180 | 220 | 260 | 300 | 350 |
| Curing time/day | 5.8 | 5.1 | 4.3 | 3.5 | 3.1 | 1.9 |
TABLE 6
From table 5, it can be seen that, comparing the experimental results in table 1, the removal of the hydroxyethylidene diphosphate component has an influence on the curing time of the high temperature resistant long-acting channeling sealing agent ii, the curing time is 1.9-5.8d, the performance index is inferior to the experimental data in table 1, and table 6 shows that after 60d of aging, the residual resistance coefficient of the core is reduced to below 10, after 180d of aging, the residual resistance coefficient of the core is only 2.5, and the high temperature blocking capability is inferior to the experimental data in table 4, which indicates that the high temperature resistant long-acting channeling sealing agent ii lacking the hydroxyethylidene diphosphate component has poor thermal stability.
Example 2
The embodiment provides a high-temperature-resistant long-acting channeling sealing agent, and the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent comprise, by mass:
8% blast furnace slag;
1% sodium fatty alcohol polyoxyethylene ether sulfate;
0.5% hydroxyethylidene diphosphate;
1.5% calcium carbonate;
0.04% acetonitrile;
0.045% sodium β -methylenedinaphthalenesulfonate;
0.035% tetraethylenepentamine;
0.015% dodecyl dimethyl benzyl ammonium chloride;
0.012% sodium gluconate;
the balance is oil field reinjection sewage.
The preparation process comprises the following steps:
(1) sequentially adding blast furnace slag, fatty alcohol-polyoxyethylene ether sodium sulfate, hydroxyl ethylidene diphosphate, calcium carbonate and acetonitrile components into a liquid preparation tank containing a proper amount of reinjection sewage, and stirring for 30 minutes at normal temperature;
(2) and then, continuously and sequentially adding the components of the beta-methylene dinaphthalene sodium sulfonate, the tetraethylenepentamine, the dodecyl dimethyl benzyl ammonium chloride and the sodium gluconate into the liquid preparation tank, and stirring for 20 minutes at normal temperature to obtain the high-temperature-resistant long-acting channeling sealing agent.
Performance test 2
The high temperature resistant long acting channeling sealing agent provided in example 2 was tested for curing time, flowability, selective plugging and temperature resistance, respectively.
(1) Curing reaction time
In order to verify the controllability of the curing time of the high-temperature-resistant long-acting channeling sealing agent, a curing time measuring experiment is carried out, and as can be seen from the experimental data in table 7, the curing reaction time of the high-temperature-resistant long-acting channeling sealing agent is prolonged to be controllable within 2.2-6.1d, so that the flash coagulation phenomenon is effectively prevented, and different formulas can be selected according to the requirements of the temperature of a field well during construction.
TABLE 7
| Temperature/. degree.C | 150 | 180 | 220 | 260 | 300 | 350 |
| Curing time/day | 6.1 | 5.4 | 4.5 | 3.6 | 3 | 2.2 |
(2) Fluidity test
At room temperature (20-25 ℃), 5 samples of the high-temperature-resistant long-acting channeling sealing agent provided in example 2 are tested by a rotary viscometer for viscosity value under the temperature condition, and the viscosity value reflects the rheological property, namely the pumpability, of the high-temperature-resistant long-acting channeling sealing agent under the condition. The experimental result in Table 8 shows that at normal temperature, the viscosity of the high-temperature-resistant long-acting channeling sealing agent is 180-193mPa & s, the pumpability meets the requirement, and the safe injection in the construction process can be ensured.
TABLE 8
(3) Selective plugging experiment
And (3) introducing high-temperature-resistant long-acting channeling sealing agents into the rock cores with different permeability level differences by adopting a double-pipe parallel model, and testing the starting pressure and the flow splitting rate.
TABLE 9
The experimental results in table 9 show that the larger the permeability level difference is, the larger the differential flow rate of the high-low permeability sand-packed pipe is, which indicates that the stronger the formation heterogeneity is, the stronger the flow-dividing ability of the high-temperature-resistant long-acting channeling-blocking agent is, and the more easily the high-temperature-resistant long-acting channeling-blocking agent enters the high-permeability part of the formation under the same condition, so that the low-permeability layer is not blocked.
(4) Evaluation of temperature resistance
The temperature resistance of the high-temperature-resistant long-acting channeling sealing agent provided in example 2 is tested by the specific method comprising the following steps: the high-temperature-resistant long-acting channeling sealing agent provided in the example 2 is injected into a rock core, and the original permeability of the rock core is 3.35 mu m2And injecting a 2.5PV high-temperature channeling sealing agent, putting the core into a 350 ℃ oven for aging, and measuring the residual resistance coefficient of the core after different aging times, wherein the results are shown in a table 10. As can be seen from Table 10, after aging for 180d, the residual resistance coefficient of the core is still kept above 17, and the core shows better high-temperature plugging capability.
Watch 10
(5) Comparative analysis experiment
Under the premise that other components of the high-temperature-resistant long-acting channeling sealing agent provided in example 2 are not changed, the tetraethylenepentamine component is removed to obtain a high-temperature-resistant long-acting channeling sealing agent III, the curing reaction time and the temperature resistance of the high-temperature-resistant long-acting channeling sealing agent III are tested, the experimental method is the same as the curing reaction time (1) and the temperature resistance evaluation (4) in example 2, and the results are shown in tables 11 and 12.
TABLE 11
| Temperature/. degree.C | 150 | 180 | 220 | 260 | 300 | 350 |
| Curing time/day | 6.5 | 55.5 | 4.7 | 3.8 | 3.3 | 2.4 |
TABLE 12
From table 11, it can be seen that, by comparing the experimental results in table 7, the curing time of the high temperature resistant long-acting channeling sealing agent iii is not greatly affected by removing the tetraethylenepentamine component, the curing time is 2.4-6.5d, the performance index is not greatly different from the experimental data in table 7, and table 12 shows that, after aging for 60d, the residual resistance coefficient of the core is reduced to below 10, after aging for 180d, the residual resistance coefficient of the core is only 3.8, and the high temperature blocking capability is not as good as the experimental data in table 10, which indicates that the high temperature resistant long-acting channeling sealing agent iii lacking the tetraethylenepentamine component has poor thermal stability.
Example 3
This example provides an example of the application of the high temperature resistant long-acting channeling sealing agent prepared in example 2 in deep channeling sealing of a fire flooding reservoir production well.
Particularly, taking 84 production wells of Du H5 wells in Liaohe oil field as an example, the well has serious gas channeling phenomenon, and the daily tail gas yield 8256Nm3The application effect becomes poor. In order to effectively control the adverse effects of the gas channeling phenomenon, fireflood production well shut-in is performed on the well.
The specific construction process comprises the following steps: the dosage of the high-temperature resistant long-acting channeling sealing agent is 650m3The discharge capacity is 12m3And h, the construction pressure is 5.2MPa when the injection is started, the construction pressure is slowly increased in the whole process, and the construction ending pressure is 8.6 MPa.
After the measures are taken, the steam injection pressure is increased by 2.8MPa, the steam absorption of a high permeability layer is reduced by 29.5 percent, the steam absorption of a medium and low permeability layer is increased to 43.6 percent, and the longitudinal utilization degree is obviously improved; day(s)The average produced tail gas amount is 1853Nm3Reduced 6403Nm compared to before the measure3The production of the well tail gas is effectively controlled; the daily oil production is increased from 1.1t to 2.9t in the last period, and compared with the oil increase 568t in the last period, the oil increase effect is obvious.
Claims (10)
1. The high-temperature-resistant long-acting channeling sealing agent comprises the following raw materials in percentage by mass:
4-8% of blast furnace slag, 0.5-1.5% of sodium fatty alcohol-polyoxyethylene ether sulfate, 0.3-0.7% of hydroxyethylidene diphosphate, 0.5-2% of calcium carbonate, 0.02-0.06% of acetonitrile, 0.02-0.07% of sodium beta-methylene dinaphthalene sulfonate, 0.01-0.05% of tetraethylenepentamine, 0.006-0.018% of dodecyl dimethyl benzyl ammonium chloride, 0.008-0.015% of sodium gluconate and the balance of water.
2. The high temperature resistant long-acting channeling sealing agent according to claim 1, wherein the proportion of the blast furnace slag is 5.5-8% based on 100% of the total mass of raw materials for preparing the high temperature resistant long-acting channeling sealing agent.
3. The high-temperature-resistant long-acting channeling sealing agent as claimed in claim 1, wherein the ratio of the sodium fatty alcohol-polyoxyethylene ether sulfate is 0.6-1% based on 100% of the total mass of raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent.
4. The high-temperature-resistant long-acting channeling sealing agent as claimed in claim 1, wherein the percentage of the hydroxyethylidene diphosphate is 0.35-0.5% based on 100% of the total mass of the raw materials for preparing the high-temperature-resistant long-acting channeling sealing agent.
5. The high temperature resistant long-acting channeling sealing agent according to claim 1,
the proportion of the calcium carbonate is 0.8-1.5%;
the proportion of the acetonitrile is 0.03-0.04%.
6. The high temperature resistant long-acting channeling sealing agent according to claim 1,
the proportion of tetraethylenepentamine is 0.025-0.035%;
the proportion of the dodecyl dimethyl benzyl ammonium chloride is 0.009-0.015%.
7. The high temperature resistant long-acting channeling sealing agent according to claim 1,
the proportion of the beta-methylene dinaphthalene sodium sulfonate is 0.04-0.045%;
the ratio of sodium gluconate is 0.01-0.012%.
8. The high temperature resistant long-acting channeling sealing agent of claim 1, wherein the water is oilfield reinjection sewage.
9. The method for preparing the high temperature resistant long-acting channeling sealing agent as claimed in any one of claims 1 to 8, which comprises the following steps:
mixing blast furnace slag, fatty alcohol-polyoxyethylene ether sodium sulfate, hydroxyl ethylidene diphosphate, calcium carbonate, acetonitrile and water to obtain a mixed solution;
and mixing the mixed solution with beta-methylene dinaphthalene sodium sulfonate, tetraethylene pentamine, dodecyl dimethyl benzyl ammonium chloride and sodium gluconate to obtain the high-temperature-resistant long-acting channeling sealing agent.
10. The use of the high temperature resistant long-acting channeling sealing agent as claimed in any one of claims 1 to 8 in deep channeling sealing of a fire flooding reservoir at a temperature of more than 350 ℃.
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| CN1587638A (en) * | 2004-09-17 | 2005-03-02 | 辽河石油勘探局 | Profile control and sand fixing integrated technology for heat oil production well |
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| CN109294539A (en) * | 2018-09-25 | 2019-02-01 | 中国石油天然气股份有限公司 | Fire flooding well environment-friendly channeling sealing agent and preparation method and application thereof |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN1587638A (en) * | 2004-09-17 | 2005-03-02 | 辽河石油勘探局 | Profile control and sand fixing integrated technology for heat oil production well |
| CN105484697A (en) * | 2015-12-22 | 2016-04-13 | 中国石油天然气股份有限公司 | Profile control channeling sealing method for super heavy oil reservoir |
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