CN113153209A - Multi-medium composite huff and puff development method for heavy oil reservoir - Google Patents
Multi-medium composite huff and puff development method for heavy oil reservoir Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 27
- 238000011161 development Methods 0.000 title claims abstract description 22
- 239000000295 fuel oil Substances 0.000 title claims abstract description 17
- 239000002131 composite material Substances 0.000 title claims description 8
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 29
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 28
- 239000004088 foaming agent Substances 0.000 claims abstract description 24
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Chemical compound NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 claims abstract description 17
- 239000004202 carbamide Substances 0.000 claims abstract description 17
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 10
- 239000007789 gas Substances 0.000 claims description 28
- 239000012530 fluid Substances 0.000 claims description 18
- 239000003431 cross linking reagent Substances 0.000 claims description 12
- 229920000642 polymer Polymers 0.000 claims description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 11
- 238000002347 injection Methods 0.000 claims description 9
- 239000007924 injection Substances 0.000 claims description 9
- 238000006073 displacement reaction Methods 0.000 claims description 8
- 239000003381 stabilizer Substances 0.000 claims description 8
- 210000001124 body fluid Anatomy 0.000 claims description 7
- 239000010839 body fluid Substances 0.000 claims description 7
- 230000009467 reduction Effects 0.000 claims description 7
- BPQQTUXANYXVAA-UHFFFAOYSA-N Orthosilicate Chemical compound [O-][Si]([O-])([O-])[O-] BPQQTUXANYXVAA-UHFFFAOYSA-N 0.000 claims description 6
- 239000004604 Blowing Agent Substances 0.000 claims description 4
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 claims description 4
- 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 4
- 229910052804 chromium Inorganic materials 0.000 claims description 4
- 239000011651 chromium Substances 0.000 claims description 4
- 239000004927 clay Substances 0.000 claims description 4
- 239000007788 liquid Substances 0.000 claims description 4
- 229920002401 polyacrylamide Polymers 0.000 claims description 4
- 150000003839 salts Chemical class 0.000 claims description 4
- 229910052708 sodium Inorganic materials 0.000 claims description 4
- 239000011734 sodium Substances 0.000 claims description 4
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 4
- 239000004711 α-olefin Substances 0.000 claims description 4
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 3
- 239000003546 flue gas Substances 0.000 claims description 3
- 125000001273 sulfonato group Chemical group [O-]S(*)(=O)=O 0.000 claims description 3
- 239000004094 surface-active agent Substances 0.000 claims description 3
- 230000015784 hyperosmotic salinity response Effects 0.000 claims description 2
- 238000007664 blowing Methods 0.000 claims 1
- 239000003921 oil Substances 0.000 abstract description 28
- 239000010779 crude oil Substances 0.000 abstract description 16
- 238000004519 manufacturing process Methods 0.000 abstract description 14
- 238000011084 recovery Methods 0.000 abstract description 9
- 230000001603 reducing effect Effects 0.000 abstract description 5
- 230000000737 periodic effect Effects 0.000 abstract description 4
- 230000008901 benefit Effects 0.000 abstract description 3
- 230000001502 supplementing effect Effects 0.000 abstract description 3
- 230000000694 effects Effects 0.000 description 8
- 230000000903 blocking effect Effects 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 230000006872 improvement Effects 0.000 description 4
- 238000010793 Steam injection (oil industry) Methods 0.000 description 3
- 230000005465 channeling Effects 0.000 description 3
- 238000005516 engineering process Methods 0.000 description 3
- 239000003129 oil well Substances 0.000 description 3
- 239000011435 rock Substances 0.000 description 3
- 238000005345 coagulation Methods 0.000 description 2
- 230000015271 coagulation Effects 0.000 description 2
- 239000002270 dispersing agent Substances 0.000 description 2
- 239000006260 foam Substances 0.000 description 2
- 238000005187 foaming Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- 239000013589 supplement Substances 0.000 description 2
- 238000005406 washing Methods 0.000 description 2
- HNNQYHFROJDYHQ-UHFFFAOYSA-N 3-(4-ethylcyclohexyl)propanoic acid 3-(3-ethylcyclopentyl)propanoic acid Chemical compound CCC1CCC(CCC(O)=O)C1.CCC1CCC(CCC(O)=O)CC1 HNNQYHFROJDYHQ-UHFFFAOYSA-N 0.000 description 1
- 238000010795 Steam Flooding Methods 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 230000009471 action 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
- 239000002981 blocking agent Substances 0.000 description 1
- 238000007906 compression Methods 0.000 description 1
- 239000003599 detergent Substances 0.000 description 1
- 238000009792 diffusion process Methods 0.000 description 1
- 238000001802 infusion Methods 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 150000004668 long chain fatty acids Chemical class 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000000344 soap Substances 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
- 238000003756 stirring Methods 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
- 238000004227 thermal cracking Methods 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
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The invention provides a complex huff and puff development method of a heavy oil reservoir multi-element medium. The method comprises the following steps: injecting a high-temperature plugging agent into the stratum; after the high-temperature plugging agent is coagulated, injecting a viscosity reducer, a foaming agent and non-condensable gas, or injecting the viscosity reducer, the foaming agent and urea; and finally injecting steam into the formation. The invention realizes the purposes of improving the oil layer profile utilization degree, reducing the crude oil viscosity, supplementing the stratum energy, improving the periodic oil production and oil-gas ratio, improving the oil reservoir recovery ratio and increasing the economic benefit by sequentially injecting the multi-element medium of high-temperature plugging agent, viscosity reducer, foaming agent and non-condensable gas (or urea) into the bottom layer before injecting steam.
Description
Technical Field
The invention relates to the technical field of oil reservoir exploitation, in particular to a heavy oil reservoir multi-medium composite huff and puff development method.
Background
At present, the heavy oil thermal recovery development modes mainly comprise steam huff and puff, steam flooding, fireflooding and the like. Steam huff and puff is a relatively simple and mature thick oil development mode that a certain amount of steam is injected into an oil well, the well is closed for a period of time, and after the heat energy of the steam is diffused to an oil layer, the well is opened for production. The steam huff and puff operation process can be divided into three stages, namely steam injection, well stewing and recovery, in the steam huff and puff development process, development contradictions such as serious steam channeling among wells, low oil layer profile utilization degree, high crude oil viscosity, short effective production period, low formation energy, poor drainage capacity and the like exist, the development contradictions are more severe along with the extension of production time, the production contradictions cannot be effectively solved by a single auxiliary medium, and the development effect is gradually reduced.
Disclosure of Invention
The invention mainly aims to provide a heavy oil reservoir multi-medium composite huff-puff development method to solve the problems of serious cross-over of steam between wells, low oil layer profile exploitation degree, high crude oil viscosity, short effective production period, low stratum energy, poor drainage capacity and the like in the steam huff-puff process in the prior art.
In order to achieve the above object, according to an aspect of the present invention, there is provided a heavy oil reservoir multi-media composite huff and puff development method, comprising: injecting a high-temperature plugging agent into the stratum; after the high-temperature plugging agent is coagulated, injecting a viscosity reducer, a foaming agent and non-condensable gas, or injecting the viscosity reducer, the foaming agent and urea; and finally injecting steam into the formation.
Furthermore, the high-temperature plugging agent has the temperature resistance of more than or equal to 320 ℃, the pressure resistance of more than or equal to 12MPa, the curing time of less than or equal to 1.5d and the salt-resistant viscosity of less than 60mPa & s.
Further, the high-temperature plugging agent comprises: the pad fluid comprises a polymer, a cross-linking agent and a stabilizing agent, wherein the polymer is preferably polyacrylamide, the cross-linking agent is organic chromium, and the stabilizing agent is clay; more preferably, the weight ratio of the polymer to the cross-linking agent is 100: 0.5-5; a host fluid comprising a silicate-based inorganic profile control system; and a displacement fluid, the displacement fluid being water; the step of injecting the high temperature plugging agent into the formation comprises: and sequentially injecting the pad fluid, the main body fluid and the displacing fluid into the stratum.
Further, the injection volume of the high-temperature plugging agent is calculated according to the injection volume of the main body fluid, specifically to
Wherein r is the profile control radius, h is the profile control height,
is porosity.
Furthermore, the temperature resistance of the viscosity reducer is more than or equal to 320 ℃, the pressure resistance of the viscosity reducer is more than or equal to 12MPa, and the indoor viscosity reduction rate of the viscosity reducer is more than or equal to 75 percent.
Further, the viscosity reducer is a surfactant SDCY of the Sanda New technology corporation of Clarity.
Furthermore, the foaming agent has the temperature resistance of more than or equal to 320 ℃, the salt tolerance of more than or equal to 2400mg/L, the half-life period of more than or equal to 100min and the foaming volume of more than or equal to 500 ml.
Further, the foaming agent is a sulfonate foaming agent, and is preferably alpha-olefin sodium sulfonate LY-I.
Further, the non-condensable gas is N2、CO2Or flue gas, preferably, non-condensable gas is injected in a volume of
Wherein r is the profile control radius, h is the profile control height,
is porosity.
Further, the injection concentration of urea is the saturation concentration.
The invention provides a complex huff and puff development method of a heavy oil reservoir multi-element medium, which comprises the following steps: injecting a high-temperature plugging agent into the stratum; after the high-temperature plugging agent is coagulated, injecting a viscosity reducer, a foaming agent and non-condensable gas, or injecting the viscosity reducer, the foaming agent and urea; and finally injecting steam into the formation. The invention realizes the purposes of improving the oil layer profile utilization degree, reducing the crude oil viscosity, supplementing the stratum energy, improving the periodic oil production and oil-gas ratio, improving the oil reservoir recovery ratio and increasing the economic benefit by sequentially injecting the multi-element medium of high-temperature plugging agent, viscosity reducer, foaming agent and non-condensable gas (or urea) into the bottom layer before injecting steam.
Detailed Description
It should be noted that the embodiments and features of the embodiments in the present application may be combined with each other without conflict. The present invention will be described in detail with reference to examples.
As described in the background section, the prior art has the problems of severe steam channeling between wells, low oil layer profile exploitation degree, high crude oil viscosity, short effective production period, low formation energy, poor drainage capacity and the like during steam huff and puff.
In order to solve the problems, the invention provides a complex huff and puff development method of a heavy oil reservoir multi-element medium, which comprises the following steps: injecting a high-temperature plugging agent into the stratum; after the high-temperature plugging agent is coagulated, injecting a viscosity reducer, a foaming agent and non-condensable gas, or injecting the viscosity reducer, the foaming agent and urea; and finally injecting steam into the formation.
The invention realizes the purposes of improving the oil layer profile utilization degree, reducing the crude oil viscosity, supplementing the stratum energy, improving the periodic oil production and oil-gas ratio, improving the oil reservoir recovery ratio and increasing the economic benefit by sequentially injecting the multi-element medium of high-temperature plugging agent, viscosity reducer, foaming agent and non-condensable gas (or urea) into the bottom layer before injecting steam. Specifically, the multi-medium composite huff and puff is a development mode for exploiting thick oil by injecting multi-phase media such as steam, urea, non-condensate gas, a viscosity reducer, a foaming agent, a high-temperature plugging agent and the like into an oil well and opening the well for production after closing the well for a period of time, and is a derivative development technology based on steam huff and puff. The method has the characteristics of comprehensively playing multiple effects of thermal viscosity reduction and chemical viscosity reduction of various media, expansion of steam wave and volume, adjustment of oil layer profile utilization, supplement of stratum energy, improvement of oil washing efficiency, improvement of recovery ratio and the like, and realizing economic and effective development of the heavy oil reservoir.
The following is a detailed description of the principles of the development method of the present invention:
the high-temperature plugging agent is injected into the stratum to sequentially plug a high-permeability layer section (zone) or a steam channeling channel, and after the high-temperature plugging agent is condensed, media such as a viscosity reducer, non-condensable gas (or urea), a foaming agent and the like are injected. Thermal cracking of urea to produce non-condensable gas CO2And NH3，CO2The gas is partially saturated and dissolved in Crude Oil (CO)2The solubility of gas in crude oil is 3-9 times higher than that of gas in water), the viscosity of the crude oil is greatly reduced, and the fluidity of the crude oil is improved; part of CO exists in oil layer in free state and after compression2During recovery, the gas expands in volume due to the reduction of pressure and dissolves CO in crude oil2And the separation is carried out, the flow-back of crude oil in the stratum is accelerated, the liquid production speed is improved, and the gas flooding effect is realized. NH (NH)3The high-viscosity heavy oil detergent is very soluble in water, reacts with long-chain fatty acid, naphthenic acid and the like in the heavy oil to generate soap substances with surface activity, can well reduce the viscosity of the heavy oil, can reduce the interfacial tension between oil water and stratum rock, changes the wettability of the stratum rock, changes the original lipophilicity of the stratum rock into hydrophilicity, effectively strips the stratum from crude oil, and improves the oil washing efficiency. The foaming agent is foamed for the second time under the stirring of the non-condensable gas to form foam fluid, and the foam fluid has the characteristics of defoaming when meeting oil, being stable when meeting water, not blocking an oil layer when blocking a water layer, having a stronger blocking effect on a high-permeability layer and a weaker blocking effect on a low-permeability layer, and the non-condensable gas can effectively mix the viscosity reducer with the viscosity reducer in the steam injection processMixing with crude oil thoroughly, and enlarging the swept volume of steam. The synergistic effect of several media can reduce the viscosity of crude oil, supplement stratum energy, improve the oil layer profile, improve oil displacement efficiency and raise oil reservoir recovery efficiency.
Based on the complex huff and puff development method of the heavy oil reservoir multi-element medium provided by the invention, the following effects can be achieved: (1) the viscosity reduction rate of the thickened oil reaches more than 89%; (2) the improvement rate of the steam absorption section reaches 73 percent; (3) the production cycle is prolonged by more than 30 percent; (4) the development recovery is increased by at least 7 percentage points.
In a preferred embodiment, the high-temperature plugging agent has the temperature resistance of more than or equal to 320 ℃, the pressure resistance of more than or equal to 12MPa, the curing time of less than or equal to 1.5d and the salt-resistant viscosity of less than 60 mPa. The high-temperature plugging agent has better performance and can play a better coagulation effect in a high-salinity high-temperature heavy oil reservoir stratum.
More preferably, the high temperature plugging agent comprises: the pad fluid comprises a polymer, a cross-linking agent and a stabilizing agent, wherein the polymer is preferably polyacrylamide, the cross-linking agent is organic chromium, and the stabilizing agent is clay; more preferably, the weight ratio of the polymer to the cross-linking agent is 100: 0.5-5; a host fluid comprising a silicate-based inorganic profile control system (such as GK-01 from Haxin Bentonite, Inc., municipality, Buckel Mongolia, the ingredients comprising a silicate and a stabilizing dispersant); and a displacement fluid, the displacement fluid being water; the step of injecting the high temperature plugging agent into the formation comprises: and sequentially injecting the pad fluid, the main body fluid and the displacing fluid into the stratum.
In order to better perform the blocking function, in a preferred embodiment, the injection volume of the high-temperature blocking agent is calculated according to the injection volume of the main body fluid, in particular
Wherein r is the profile control radius, h is the profile control height,
is porosity.
In a preferred embodiment, the temperature resistance of the viscosity reducer is more than or equal to 320 ℃, the pressure resistance of the viscosity reducer is more than or equal to 12MPa, and the indoor viscosity reduction rate is more than or equal to 75 percent. More preferably, the viscosity reducer is a surfactant class SDCY from samader technologies ltd. The viscosity reducer has a better viscosity reducing effect, and has a more obvious effect on reducing the viscosity of crude oil.
In a preferred embodiment, the foaming agent has a temperature resistance of 320 ℃ or higher, a salt resistance of 2400mg/L or higher, a half-life of 100min or higher and a foaming volume of 500ml or higher. More preferably, the blowing agent is a sulfonate type blowing agent, preferably sodium alpha-olefin sulfonate LY-I.
In order to further improve the action and effect of the non-condensable gas and also to improve the safety of the working process, in a preferred embodiment the non-condensable gas is N2、CO2Or flue gas, preferably, non-condensable gas is injected in a volume of
(the gas compressibility refers to the corrected value for the deviation of the actual gas properties from the ideal gas properties), where r is the profile radius, h is the profile height,
is porosity.
In a preferred embodiment, the injection concentration of urea is the saturation concentration. For example, the urea saturation concentration is about 71.5% wt at 60 ℃. Preferably, the concentration of the blowing agent is 2.5 to 3.0% wt. The concentrations in these examples are based on the mass concentration of the components after the solution preparation.
The present application is described in further detail below with reference to specific examples, which should not be construed as limiting the scope of the invention as claimed.
Example 1
Taking a wind city heavy oil reservoir as an example, the specific multi-medium composite huff and puff development process is as follows:
a1 borehole porosity 31.3%, reservoir thickness 13 m;
the oil well waiting for the rotating wheel is firstly extruded into 10m in sequence3Pre-infusion(which comprises polymer, crosslinking agent and stabilizer, wherein the polymer is polyacrylamide, the crosslinking agent is organic chromium, the stabilizer is clay, the weight ratio of the polymer to the crosslinking agent is 100: 1;), 319m of main body fluid3(silicate inorganic profile control system GK-01 comprising silicate and stable dispersant), and clear water of displacement liquid 15m3The back diffusion pressure is 30 minutes, and the well is closed and the coagulation is waited for 36 hours after the well is back washed for 1 week;
then sequentially extruding 14 tons of viscosity reducer SDCY (the mass ratio of the viscosity reducer to clear water is 1:7.5 for preparing solution), 1.6 tons of alpha-olefin sodium sulfonate LY-I foaming agent and 18 tons of urea (the foaming agent and the urea are prepared by hot water at 60 ℃ in advance);
finally, 1940 ton of high-dryness steam is injected, the steam injection speed is 130t/d, and the well is opened for production after 2-3 days of well stewing.
Finally, the measurement shows that the periodic oil production is 409 tons and is improved by 318 tons, and the oil-steam ratio is 0.211 and is improved by 0.158.
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 (10)
1. A heavy oil reservoir multi-medium composite huff and puff development method is characterized by comprising the following steps:
injecting a high-temperature plugging agent into the stratum;
after the high-temperature plugging agent is coagulated, injecting a viscosity reducer, a foaming agent and non-condensable gas, or injecting the viscosity reducer, the foaming agent and urea;
and finally injecting steam into the formation.
2. The method according to claim 1, wherein the high temperature plugging agent has a temperature resistance of not less than 320 ℃, a pressure resistance of not less than 12MPa, a curing time of not more than 1.5d, and a salt resistance viscosity of less than 60 mPa-s.
3. The method of claim 2, wherein the high temperature plugging agent comprises:
a pad fluid comprising a polymer, a cross-linking agent and a stabilizer, preferably the polymer is polyacrylamide, the cross-linking agent is organic chromium, and the stabilizer is clay; more preferably, the weight ratio of the polymer to the cross-linking agent is 100: 0.5-5;
a host fluid comprising a silicate-based inorganic profile control system; and
a displacement liquid, wherein the displacement liquid is water;
the step of injecting the high temperature plugging agent into the formation comprises: and sequentially injecting the pad fluid, the main body fluid and the displacing fluid into the stratum.
4. Method according to claim 3, wherein the injection volume of the high temperature plugging agent is calculated from the injection volume of the host body fluid, in particular
Wherein r is the profile control radius, h is the profile control height,
is porosity.
5. The method as claimed in any one of claims 1 to 4, wherein the viscosity reducer has a temperature resistance of not less than 320 ℃, a pressure resistance of not less than 12MPa, and an indoor viscosity reduction rate of not less than 75%.
6. The method according to claim 5, wherein the viscosity reducer is a surfactant class SDCY.
7. The method according to any one of claims 1 to 4, wherein the blowing agent has a temperature resistance of not less than 320 ℃, a salt tolerance of not less than 2400mg/L, a half-life of not less than 100min and a blowing volume of not less than 500 ml.
8. The method according to claim 7, wherein the foaming agent is a sulfonate foaming agent, preferably sodium alpha olefin sulfonate LY-I.
9. The method according to any one of claims 1 to 4, wherein the non-condensable gas is N2、CO2Or flue gas, preferably, the non-condensable gas is injected in a volume of
Wherein r is the profile control radius, h is the profile control height,
is porosity.
10. Method according to any one of claims 1 to 4, characterized in that the injection concentration of urea is the saturation concentration.
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117027745A (en) * | 2023-10-10 | 2023-11-10 | 中国石油大学(华东) | Method for strengthening thickened oil thermal recovery by using non-condensate gas composite aquathermolysis catalyst |
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| US20090078414A1 (en) * | 2007-09-25 | 2009-03-26 | Schlumberger Technology Corp. | Chemically enhanced thermal recovery of heavy oil |
| CN101481604A (en) * | 2009-01-19 | 2009-07-15 | 中国石油大学(华东) | Gel foam selective water blockoff agent and use thereof |
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Application publication date: 20210723 |