CN107882531B - Selective water control channeling sealing method for flooding production well of water-flooded oil reservoir - Google Patents
Selective water control channeling sealing method for flooding production well of water-flooded oil reservoir Download PDFInfo
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- CN107882531B CN107882531B CN201711248875.3A CN201711248875A CN107882531B CN 107882531 B CN107882531 B CN 107882531B CN 201711248875 A CN201711248875 A CN 201711248875A CN 107882531 B CN107882531 B CN 107882531B
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 47
- 230000005465 channeling Effects 0.000 title claims abstract description 42
- 238000000034 method Methods 0.000 title claims abstract description 36
- 238000007789 sealing Methods 0.000 title claims abstract description 29
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 20
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 16
- ZNCPFRVNHGOPAG-UHFFFAOYSA-L sodium oxalate Chemical group [Na+].[Na+].[O-]C(=O)C([O-])=O ZNCPFRVNHGOPAG-UHFFFAOYSA-L 0.000 claims abstract description 14
- 229940039790 sodium oxalate Drugs 0.000 claims abstract description 14
- 239000003513 alkali Substances 0.000 claims abstract description 10
- 230000000903 blocking effect Effects 0.000 claims abstract description 6
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 6
- 239000004088 foaming agent Substances 0.000 claims abstract description 6
- 229940051841 polyoxyethylene ether Drugs 0.000 claims abstract description 6
- 229920000056 polyoxyethylene ether Polymers 0.000 claims abstract description 6
- 239000000126 substance Substances 0.000 claims abstract description 6
- 239000004094 surface-active agent Substances 0.000 claims abstract description 6
- 239000002981 blocking agent Substances 0.000 claims abstract description 5
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims abstract description 4
- RSWGJHLUYNHPMX-UHFFFAOYSA-N Abietic-Saeure Natural products C12CCC(C(C)C)=CC2=CCC2C1(C)CCCC2(C)C(O)=O RSWGJHLUYNHPMX-UHFFFAOYSA-N 0.000 claims abstract description 3
- 108010082495 Dietary Plant Proteins Proteins 0.000 claims abstract description 3
- KHPCPRHQVVSZAH-HUOMCSJISA-N Rosin Natural products O(C/C=C/c1ccccc1)[C@H]1[C@H](O)[C@@H](O)[C@@H](O)[C@@H](CO)O1 KHPCPRHQVVSZAH-HUOMCSJISA-N 0.000 claims abstract description 3
- 239000000344 soap Substances 0.000 claims abstract description 3
- KHPCPRHQVVSZAH-UHFFFAOYSA-N trans-cinnamyl beta-D-glucopyranoside Natural products OC1C(O)C(O)C(CO)OC1OCC=CC1=CC=CC=C1 KHPCPRHQVVSZAH-UHFFFAOYSA-N 0.000 claims abstract description 3
- 238000002347 injection Methods 0.000 claims description 10
- 239000007924 injection Substances 0.000 claims description 10
- AXCZMVOFGPJBDE-UHFFFAOYSA-L calcium dihydroxide Chemical compound [OH-].[OH-].[Ca+2] AXCZMVOFGPJBDE-UHFFFAOYSA-L 0.000 claims description 7
- 239000000920 calcium hydroxide Substances 0.000 claims description 6
- 229910001861 calcium hydroxide Inorganic materials 0.000 claims description 6
- 229920002401 polyacrylamide Polymers 0.000 claims description 6
- 239000002562 thickening agent Substances 0.000 claims description 5
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 claims description 4
- DPXJVFZANSGRMM-UHFFFAOYSA-N acetic acid;2,3,4,5,6-pentahydroxyhexanal;sodium Chemical compound [Na].CC(O)=O.OCC(O)C(O)C(O)C(O)C=O DPXJVFZANSGRMM-UHFFFAOYSA-N 0.000 claims description 4
- 239000001768 carboxy methyl cellulose Substances 0.000 claims description 4
- 239000011734 sodium Substances 0.000 claims description 4
- 229910052708 sodium Inorganic materials 0.000 claims description 4
- 235000019812 sodium carboxymethyl cellulose Nutrition 0.000 claims description 4
- 229920001027 sodium carboxymethylcellulose Polymers 0.000 claims description 4
- 239000000243 solution Substances 0.000 claims description 4
- 239000002245 particle Substances 0.000 claims description 3
- 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 description 2
- RCEAADKTGXTDOA-UHFFFAOYSA-N OS(O)(=O)=O.CCCCCCCCCCCC[Na] Chemical compound OS(O)(=O)=O.CCCCCCCCCCCC[Na] RCEAADKTGXTDOA-UHFFFAOYSA-N 0.000 claims description 2
- 239000010426 asphalt Substances 0.000 claims description 2
- 238000007865 diluting Methods 0.000 claims description 2
- 238000011978 dissolution method Methods 0.000 claims description 2
- 239000012188 paraffin wax Substances 0.000 claims description 2
- 238000005516 engineering process Methods 0.000 abstract description 9
- PMZURENOXWZQFD-UHFFFAOYSA-L Sodium Sulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=O PMZURENOXWZQFD-UHFFFAOYSA-L 0.000 abstract description 2
- 229910052938 sodium sulfate Inorganic materials 0.000 abstract description 2
- 235000011152 sodium sulphate Nutrition 0.000 abstract description 2
- 239000003921 oil Substances 0.000 description 32
- 239000007789 gas Substances 0.000 description 15
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 12
- 238000002485 combustion reaction Methods 0.000 description 9
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 7
- 238000010276 construction Methods 0.000 description 7
- 239000007788 liquid Substances 0.000 description 7
- 239000001301 oxygen Substances 0.000 description 7
- 229910052760 oxygen Inorganic materials 0.000 description 7
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 6
- 239000001569 carbon dioxide Substances 0.000 description 6
- 229910002092 carbon dioxide Inorganic materials 0.000 description 6
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 6
- 235000011116 calcium hydroxide Nutrition 0.000 description 5
- 239000010779 crude oil Substances 0.000 description 5
- 230000000694 effects Effects 0.000 description 4
- 238000011065 in-situ storage Methods 0.000 description 4
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 239000007787 solid Substances 0.000 description 3
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- 238000006073 displacement reaction Methods 0.000 description 2
- 239000000295 fuel oil Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 235000019353 potassium silicate Nutrition 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- NTHWMYGWWRZVTN-UHFFFAOYSA-N sodium silicate Chemical compound [Na+].[Na+].[O-][Si]([O-])=O NTHWMYGWWRZVTN-UHFFFAOYSA-N 0.000 description 2
- 239000002253 acid Substances 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 238000010420 art technique Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000000440 bentonite Substances 0.000 description 1
- 229910000278 bentonite Inorganic materials 0.000 description 1
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000010411 cooking Methods 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000001125 extrusion Methods 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000004537 pulping Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000001603 reducing effect Effects 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 230000002269 spontaneous effect Effects 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Classifications
-
- 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
- E21B33/12—Packers; Plugs
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
-
- 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
-
- 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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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Soil Conditioners And Soil-Stabilizing Materials (AREA)
- Sealing Material Composition (AREA)
Abstract
The invention provides a selective water control channeling sealing method for a fire flooding production well of a water flooded oil reservoir, which comprises the following steps: blocking the gas channeling dominant channel by using a channeling blocking agent; and selectively plugging the near-well high-water-content dominant channel. The channeling sealing agent comprises an alkali-resistant surfactant foaming agent and an auxiliary alkali reducing agent. The alkali-resistant surfactant foaming agent is selected from one or more of sodium dodecyl sulfate, fatty alcohol-polyoxyethylene ether sodium sulfate, rosin soap substances, animal and vegetable protein substances, papermaking black liquor and the like, and the auxiliary alkali reducing agent is sodium oxalate. The invention relates to a selective water control and channeling sealing integrated technology.
Description
Technical Field
The invention relates to a selective water control channeling sealing method for a water flooded reservoir fire flooding production well, in particular to a method for implementing selective water control channeling sealing for the water flooded reservoir fire flooding production well, and belongs to the field of oil extraction production.
Background
The in-situ combustion technology is also called fire flooding, and is an exploitation technology capable of greatly improving the recovery ratio of a heavy oil reservoir, wherein the fire flooding is to use heavy components in stratum crude oil as fuel, use air or oxygen-enriched gas as combustion improver, adopt methods such as spontaneous combustion and artificial ignition to enable the temperature of the oil reservoir to reach the ignition point of the crude oil, continuously inject the combustion improver into the oil reservoir to enable the crude oil in the oil reservoir to be continuously combusted, generate a large amount of heat through combustion reaction, heat the oil reservoir to enable the temperature of the oil reservoir to rise to 600-700 ℃, crack the heavy components at high temperature, and use the injected gas, the light oil generated by cracking the heavy oil, the gas generated by combustion and water vapor to drive the crude oil to flow to a production well and extract the crude oil from the.
At present, key technologies and patent methods for in-situ combustion mainly focus on the following researches: ignition method, well completion method, tracing method, monitoring method, produced gas treatment, auxiliary exploitation, profile control plugging, indoor simulation and the like. The technology of flooding the oil reservoir with water has been developed in recent years, but some contradictions have been found. For a certain block, the stratum thickness is 69.9m, the sand body thickness is 33.6m, the average effective thickness of an oil layer is 24.5m, the water content of the block is up to 91%, and oil wells with water content higher than 90% account for 67% of the total number of wells, so that the block is a typical water flooded oil reservoir. Under the condition that the gas injection standard of an initial injection well is 3000 square/hour, 8 production wells see gas comprehensively, but only 2 production wells see the oil displacement effect, which indicates that the oil saturation of a gas channeling channel is low, and the production requirement under the fire flooding condition of a high water-cut oil reservoir cannot be met by the common selective channeling sealing technology.
The prior in-situ combustion production oil well liquid production profile adjusting and plugging technology at present comprises the following steps: gel profile control plugging, namely, pretreating a gas production oil layer by using polymer to form gel, and then sealing by using water glass; and the water glass is added with silica or bentonite to realize the plugging of the oil layer; in addition, there is also a class in which plugging is directly performed with solid particles.
These prior art techniques still suffer from a number of deficiencies, including mainly: plugging is performed in a general way, and the selectivity is poor; the blockage is difficult to remove after the blockage; the construction cost is high.
Carbon dioxide, hydrogen sulfide gas, oxygen and the like produced in the fireflood production well belong to harmful gases and need to be reduced as much as possible. There are several channeling methods that are primarily directed to acid gases, such as: cn201510411805.x discloses a slaked lime plugging method in the process of in-situ combustion exploitation, and the like. But do not meet the actual needs of the oilfield site.
Disclosure of Invention
The invention aims to develop a selective water control channeling sealing integrated technology.
According to a specific embodiment of the invention, the invention provides a selective water control channeling sealing method for a fire flooding production well of a water flooded reservoir, which comprises the following steps:
blocking the gas channeling dominant channel by using a channeling blocking agent;
and selectively plugging the near-well high-water-content dominant channel.
According to a specific embodiment of the present invention, in the method of the present invention, the channeling sealing agent comprises an alkali-resistant surfactant foaming agent and an auxiliary alkali reducing agent.
According to a specific embodiment of the present invention, in the method of the present invention, the alkali-resistant surfactant foaming agent is selected from one or more of sodium dodecyl sulfate, sodium fatty alcohol-polyoxyethylene ether sulfate, rosin soap substances, animal and vegetable protein substances, black liquor, and the like.
According to a particular embodiment of the invention, in the process of the invention, the auxiliary basic reducing agent is sodium oxalate.
In a specific embodiment of the invention, the channeling sealing agent comprises (the amount of each component is in weight percentage):
1-1.5% of sodium fatty alcohol-polyoxyethylene ether sulfate;
1% -2% of sodium oxalate;
0.01 to 0.03 percent of thickening agent;
2% -5% of calcium hydroxide clear solution (namely saturated calcium hydroxide aqueous solution);
the balance of water.
In another specific embodiment of the invention, the channeling sealing agent comprises (the amount of each component is in weight percent):
2% -3% of sodium dodecyl sulfate;
1% -2% of sodium oxalate;
0.01 to 0.03 percent of thickening agent;
2% -5% of calcium hydroxide clear solution;
the balance of water.
In the channeling sealing agent, the thickening agent is mainly used for stabilizing foam and can comprise polyacrylamide and/or sodium carboxymethyl cellulose. When polyacrylamide is selected, the molecular weight is preferably 500-2000 ten thousand, and the dosage is 0.01-0.02%. When sodium carboxymethylcellulose is selected, the amount is preferably 0.02% to 0.03%.
In another specific embodiment of the invention, the channeling sealing agent is prepared by adding 1-2% by weight of sodium oxalate into papermaking black liquor after the papermaking black liquor is properly diluted. The papermaking black liquor is pulping cooking waste liquor in the papermaking process. According to the specific embodiment of the invention, the papermaking black liquor needs to be diluted (usually by 5-10 times) for use. The added amount (1-2%) of the sodium oxalate refers to the total weight of the diluted papermaking black liquor. In addition, the papermaking black liquor can be sieved by a 200-mesh sieve, and the papermaking black liquor can be diluted for use after redundant solid matters are filtered. The black liquor can be barreled or canned for later use. When the diluted paper-making black liquor added with sodium oxalate is injected into stratum, when the stable squeezing pressure is raised by 3-5MPa or the highest pressure is up to 8-10MPa, the construction can be stopped. Normally, the injection amount of the paper making black liquor mixed with sodium oxalate is generally in the range of 2000-10000 square, namely the pressure can be reached.
The channeling sealing agent can reduce harmful gases such as carbon dioxide, hydrogen sulfide, oxygen and the like, and simultaneously utilize the Jamin effect to seal a gas channeling dominant channel, so that nitrogen is diverted, and the aim of improving the oil displacement wave and the volume is fulfilled.
According to the specific embodiment of the invention, in the selective water control channeling blocking method for the fire flooding production well of the water flooded reservoir, the specific method for blocking the gas channeling dominant channel by using the channeling blocking agent comprises the following steps:
and injecting the channeling sealing agent into the stratum, wherein the injection amount is generally 1000-10000, and closing the well for 1-3 days. The rate of injection of the channeling agent of the invention into the formation is preferably 5-15 square/hour, typically 10-15 square/hour. If the pressure is too fast, the injection speed can be reduced properly to reduce the friction, but not less than 5 square/hour.
According to the specific embodiment of the invention, in the selective water control and channeling sealing method for the fire flooding production well of the water flooded reservoir, the specific method for selectively sealing the near-well high water-cut dominant channel can be one of the following selective water plugging methods:
water shutoff of emulsified thick oil, water shutoff of oil-soluble particles by a dissolution method, water shutoff of modified asphalt, water shutoff of modified paraffin, water shutoff of weak gel polyacrylamide and the like.
More specific water shutoff operations can be performed with reference to the prior art in the field.
The method provided by the invention can be used for selectively plugging the near-well high-water-content dominant channel while channeling is sealed, and new pollution to the stratum is avoided.
In general, the beneficial effects of the invention include:
(1) the purpose is clear and the selectivity is strong.
(2) No pollution to stratum, safety and environmental protection.
(3) The original pipe column construction is simple to operate.
Detailed Description
The following examples are presented to illustrate the practice and application of the present technology, but are not intended to limit the scope of the present invention. Operations not specifically mentioned in the embodiments may be performed by referring to conventional operations in the art.
Example 1
In a certain well of Liaohe oil field, 998.3-1032.9 m of well section is treated, 16.2 m/10 layers are treated, the average effective porosity is 32%, 27 parts of daily produced liquid is produced before construction, and 1 ton of daily produced oil is produced. The papermaking black liquor (the mass concentration of the total solid matters is 8 percent) separated from the pulp of a papermaking factory is screened by a 200-mesh sieve and then canned for later use. Diluting the treated black liquor by 10 times on site, adding 1% by weight of sodium oxalate, using a pump truck, controlling the injection speed by 15 square/h, extruding into the stratum with the extrusion amount of 3000 square, and stopping the construction when the highest pressure reaches 8.3 MPa. And then using 500-square weak gel with the gel viscosity of about 2000mPa.s to control water and seal, equivalently replacing the hot sewage oil sleeve annulus, and closing the well for three days. In the initial stage after well opening, the daily produced liquid is 20 prescriptions, the daily produced oil is 4 tons, the accumulated oil is 309 tons, and the effective period is 114 days, so that obvious oil increasing and water reducing effects are achieved.
Example 2
In a certain well of the Liaohe oil field, the processing layer is a rising platform, the processing well section is 1094-1142.2m, the effective thickness/layer number is 17.8/11, and the average effective porosity is 27.87%. Before construction, 31 square of daily produced fluid and 1.5 tons of daily produced oil are detected, and the carbon dioxide content, the oxygen content and the hydrogen sulfide content in the produced fluid are respectively 15 percent, 3 percent and 552 ppm. The channeling sealing agent is prepared by clear water on site according to 1.5 percent of fatty alcohol-polyoxyethylene ether sodium sulfate, 1 percent of sodium oxalate, 0.02 percent of sodium carboxymethylcellulose and 2 percent of calcium hydroxide clear solution. And (3) squeezing the mixture into the stratum by using a pump truck, injecting 3000 square of the mixture, performing water control sealing treatment by using 78 square of emulsified thick oil, closing the well for 3 days, and opening the well for production. After the well is opened for 1 month, the content of carbon dioxide is 4.5 percent, the content of oxygen is 1 percent, and the content of hydrogen sulfide is 25 ppm. The average daily liquid yield is 28, and the daily oil yield is 3.5 tons, so that the obvious effect is achieved.
Example 3
In a certain well of Liaohe oil field, the treated well section is 942.4-987.4m, the effective thickness/layer number is 19.7/13, and the average effective porosity is 21.95%. Before construction, 25.9 parts of daily produced liquid, 0.93 ton of daily produced oil and 96.4 percent of water are contained. The produced fluid was found to have a carbon dioxide content of 18%, an oxygen content of 4.5%, and a hydrogen sulfide content of 325 ppm. The channeling sealing agent is prepared by clear water according to the clear liquid of 3 percent of lauryl sodium sulfate, 2 percent of sodium oxalate, 0.02 percent of polyacrylamide (with the molecular weight of 1500 ten thousand) and 3 percent of calcium hydroxide on site. And (5) squeezing the mixture into the stratum by using a pump truck, wherein the injection amount is 4000 square. And (4) performing water control sealing treatment by adopting a 120-square emulsified thick oil, closing the well for 3 days, and opening the well for production. After the well is opened for 1 month, the content of carbon dioxide is detected to be 2.5 percent, the content of oxygen is detected to be 0.5 percent, and the content of hydrogen sulfide is detected to be 0 ppm. The average daily liquid yield is 26.1, the daily oil yield is 4.5 tons, and obvious effects are achieved.
The above description is only a preferred embodiment of the present invention and is not intended to limit the present invention, and various modifications and changes may be made by those skilled in the art. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.
Claims (7)
1. A method for selectively controlling water and sealing channeling of a fire flooding production well of a water flooded reservoir comprises the following steps:
blocking the gas channeling dominant channel by using a channeling blocking agent;
selectively plugging a near-well high-water-content dominant channel;
wherein, the channeling sealing agent comprises an alkali-resistant surfactant foaming agent and an auxiliary alkali reducing agent;
the method for blocking the gas channeling dominant channel by adopting the channeling blocking agent comprises the following steps: injecting the channeling sealing agent into the stratum with the injection amount of 1000-10000 sides; the injection speed of the channeling sealing agent is 5-15 square/hour;
the method for selectively plugging the near-well high-water-content dominant channel selects one of the following selective water plugging methods: water shutoff for emulsified thick oil, water shutoff for oil-soluble particles by a dissolution method, water shutoff for modified paraffin or water shutoff for weak gel polyacrylamide.
2. The method of claim 1, wherein the alkali-resistant surfactant foaming agent is selected from one or more of sodium dodecyl sulfate, sodium fatty alcohol-polyoxyethylene ether sulfate, rosin soap substances, animal and vegetable protein substances and papermaking black liquor.
3. A process according to claim 1 or 2, wherein the auxiliary basic reducing agent is sodium oxalate.
4. The method of claim 1, wherein the channeling agent comprises:
1-1.5% of sodium fatty alcohol-polyoxyethylene ether sulfate or 2-3% of lauryl sodium sulfate;
1% -2% of sodium oxalate;
0.01 to 0.03 percent of thickening agent;
2% -5% of calcium hydroxide clear solution;
the balance of water.
5. The method of claim 4, wherein the thickener comprises polyacrylamide and/or sodium carboxymethylcellulose.
6. The method according to claim 1, wherein the channeling sealing agent is obtained by diluting papermaking black liquor by 5-10 times and then adding 1-2% by weight of sodium oxalate for mixing.
7. The method of claim 1, wherein the method for selectively plugging the near-well high water content dominant channel is selected from modified asphalt for water plugging.
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201711248875.3A CN107882531B (en) | 2017-12-01 | 2017-12-01 | Selective water control channeling sealing method for flooding production well of water-flooded oil reservoir |
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| CN201711248875.3A CN107882531B (en) | 2017-12-01 | 2017-12-01 | Selective water control channeling sealing method for flooding production well of water-flooded oil reservoir |
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| CN107882531A CN107882531A (en) | 2018-04-06 |
| CN107882531B true CN107882531B (en) | 2020-10-09 |
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