CN103527161A - Thermal recovery horizontal well water shut-off and profile control method - Google Patents
Thermal recovery horizontal well water shut-off and profile control method Download PDFInfo
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- CN103527161A CN103527161A CN201210226837.9A CN201210226837A CN103527161A CN 103527161 A CN103527161 A CN 103527161A CN 201210226837 A CN201210226837 A CN 201210226837A CN 103527161 A CN103527161 A CN 103527161A
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Abstract
The invention provides a thermal recovery horizontal well water shut-off and profile control method. The thermal recovery horizontal well water shut-off and profile control method includes the steps that (1) a water production interval is determined according to a thermal recovery horizontal well differential temperature test technique and oil reservoir geological conditions; (2) the steam injection volume and temperature field distribution are simulated through an oil reservoir value simulation method, an injection scheme is determined, and the injection volume of gel and plugging agents and the size of a displacement slug are optimized; (3) according to the determined injection scheme and the optimized injection volume of the gel and the injection agents, after the gel and the injection agents are injected into the water production interval, the displacement slug is injected, and ultimately steam is injected. According to the thermal recovery horizontal well water shut-off and profile control method, a high-permeability layer is plugged selectively by means of a temperature field, the steam enters an undeveloped oil layer, the steam injection profile of a reservoir is improved, and the purpose of economically and efficiently developing a thermal recovery horizontal well with high water content is achieved.
Description
Technical field
The present invention relates to technical field of petroleum extraction, particularly relate to a kind of method of horizontal well thermal recovery water plugging and profile controlling.
Background technology
Along with the raising of drilling and completion technology technology, horizontal well thermal recovery is applied more and more in oil field.The horizontal segment length of horizontal well thermal recovery, drainage area is large, can utilize the onlap of steam to improve viscous crude well yield, to tap the latent power and the dominant technology of low-grade Development of Viscous Crude Oil in current old liberated area, also be the major way of heavy crude reservoir thermal recovery Productivity Construction, height is moisture is the horizontal well thermal recovery of the subject matter that affects horizontal well thermal recovery development effectiveness, especially sieve tube completion, once comprehensive water cut raises, and also there is no at present effective water plugging and profile controlling technological measure.At present, it is large that the stifled conditioning technology ubiquity of field by using engineering risk, and cost is high, a little less than plugging strength, and the problems such as poor selectivity.So oil field development and production are actual can effectively solve the high production practice containing water problems of horizontal well thermal recovery in the urgent need to research and development.We have invented a kind of method of new horizontal well thermal recovery water plugging and profile controlling for this reason, have solved above technical problem.
Summary of the invention
The object of this invention is to provide and a kind ofly in stratum, inject gel to improve the method for the horizontal well thermal recovery water plugging and profile controlling of high moisture horizontal well thermal recovery development effectiveness.
Object of the present invention can be achieved by the following technical measures: the method for horizontal well thermal recovery water plugging and profile controlling, the method of this horizontal well thermal recovery water plugging and profile controlling comprises: step 1, and utilize horizontal well thermal recovery DTEM measuring technology to determine water exit interval in conjunction with reservoir geology situation; Step 2, simulates steam injection amount and thermal field distributes by numerical reservoir simulation method, determines injecting scheme, optimizes the injection rate of gel and blocking agent and replaces slug size; And step 3, according to this injecting scheme and this gel of optimization and the injection rate of this blocking agent determined, this gel and this blocking agent are injected after this water exit interval, inject this replacement slug, last steam injection.
Object of the present invention also can be achieved by the following technical measures:
The method of this horizontal well thermal recovery water plugging and profile controlling also comprises, after step 1, calculates the injection rate of this gel and this blocking agent according to water exit interval length, Living space and reservoir parameter.
The method of this horizontal well thermal recovery water plugging and profile controlling is also included in after step 3, stewing well 3-6 days; And carry out DTEM test, test steam entry profile and horizontal segment thermal field distribution situation.
The oil reservoir of applying the method for this horizontal well thermal recovery water plugging and profile controlling is: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, little 1000 mg/L-100000mg/L of salinity.
This gel is thermo-sensitive gel, and this blocking agent is thermosetting blocking agent.
Object of the present invention also can be achieved by the following technical measures: the method for horizontal well thermal recovery water plugging and profile controlling, it is characterized in that, and the method for this horizontal well thermal recovery water plugging and profile controlling comprises:
Step 1, utilizes horizontal well thermal recovery DTEM measuring technology to determine water exit interval in conjunction with reservoir geology situation;
Step 2, simulates steam injection amount and thermal field distributes by numerical reservoir simulation method, determines injecting scheme, optimizes the injection rate of gel and replaces slug size; And
Step 3, according to the injection rate of this gel of this injecting scheme of determining and optimization, injects this gel after this water exit interval, injects this replacement slug, last steam injection.
Object of the present invention also can be achieved by the following technical measures:
The method of this horizontal well thermal recovery water plugging and profile controlling also comprises, after step 1, calculates the injection rate of this gel according to water exit interval length, Living space and reservoir parameter.
The method of this horizontal well thermal recovery water plugging and profile controlling is also included in after step 3, stewing well 3-6 days; And carry out DTEM test, test steam entry profile and horizontal segment thermal field distribution situation.
The oil reservoir of applying the method for this horizontal well thermal recovery water plugging and profile controlling is: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, little 1000 mg/L-100000mg/L of salinity.
This gel is thermo-sensitive gel.
The method of the horizontal well thermal recovery water plugging and profile controlling in the present invention, by injecting gel, is low viscosity fluid under cryogenic conditions, preferentially enter high permeability zone, utilize reservoir temperature field, realize selective shut-off, change Reservoir Seepage passage, steam is entered and do not employ oil reservoir, improve the steam entry profile of reservoir; In addition, also can seal by injecting heat curing-type blocking agent, strengthen the plugging strength of gel rubber system, thereby reach the object of the high moisture horizontal well thermal recovery of economical and efficient exploitation.Increase oily 400t left and right by this technological measure individual well cycle, reduce moisture 10% left and right.
Accompanying drawing explanation
Fig. 1 is the flow chart of a specific embodiment of the method for horizontal well thermal recovery water plugging and profile controlling of the present invention;
Fig. 2 is the flow chart of a specific embodiment of the method for horizontal well thermal recovery water plugging and profile controlling of the present invention;
Fig. 3 is numerical reservoir simulation method simulation steam injection amount and thermal field distribution schematic diagram in one embodiment of the invention;
Fig. 4 is testing level section thermal field distribution situation schematic diagram in one embodiment of the invention.
The specific embodiment
For above and other object of the present invention, feature and advantage can be become apparent, cited below particularlyly go out preferred embodiment, and coordinate appended graphicly, be described in detail below.
As shown in Figure 1, Fig. 1 is the flow chart of a specific embodiment of the method for horizontal well thermal recovery water plugging and profile controlling of the present invention.Wherein, oil reservoir applicable elements for horizontal well thermal recovery water plugging and profile controlling new method is: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100 mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, the little 1000mg/L-100000mg/L of salinity.
In step 101, utilize horizontal well thermal recovery DTEM measuring technology to determine water exit interval in conjunction with reservoir geology situation.Particularly, service shaft and the offset well condition of production are analyzed, according to horizontal well thermal recovery DTEM test result, in conjunction with the reservoir geology overview of this well, determine water exit interval.Flow process enters into step 102.
In step 102, according to the injection rate of water exit interval length, Living space and reservoir parameter calculated for gel and blocking agent.Flow process enters into step 103.
In step 103, according to Physical simulation experiment, by numerical reservoir simulation method, simulate steam injection amount and thermal field distributes, determine injecting scheme, optimize the injection rate of gel and blocking agent and replace slug size.In an embodiment, this gel rubber system is thermo-sensitive gel, and this blocking agent is thermosetting blocking agent.In one embodiment, at Reservoir Permeability, be greater than 3000mDc, when back production water is greater than 500% in manufacturing process, use thermosetting blocking agent, this is because consider that the plugging strength of thermo-sensitive gel is not so good as heat curing-type blocking agent, and the heatproof of heat curing-type blocking agent is also better than thermo-sensitive gel, but from economic angle, consider, thermo-sensitive gel has advantage compared with heat curing-type blocking agent.Flow process enters into step 104.
In step 104, according to definite injecting scheme and the injection rate of optimization, will block up tune system (gel and blocking agent) and inject after water exit interval, inject and replace slug, last steam injection.Flow process enters into step 105.
In step 105, after injection technology finishes, stewing well 3-6 days.Flow process enters into step 106.
In step 106, carry out DTEM test, test steam entry profile and horizontal segment thermal field distribution situation.Flow process finishes.
Fig. 2 is the flow chart of another specific embodiment of the method for horizontal well thermal recovery water plugging and profile controlling of the present invention.Wherein, oil reservoir applicable elements for horizontal well thermal recovery water plugging and profile controlling new method is: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100 mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, the little 1000mg/L-100000mg/L of salinity.
In step 201, utilize horizontal well thermal recovery DTEM measuring technology to determine water exit interval in conjunction with reservoir geology situation.Particularly, service shaft and the offset well condition of production are analyzed, according to horizontal well thermal recovery DTEM test result, in conjunction with the reservoir geology overview of this well, determine water exit interval.Flow process enters into step 202.
In step 202, according to the injection rate of water exit interval length, Living space and reservoir parameter calculated for gel.Flow process enters into step 203.
In step 203, according to Physical simulation experiment, by numerical reservoir simulation method, simulate steam injection amount and thermal field distributes, determine injecting scheme, optimize the injection rate of gel and replace slug size.In an embodiment, this gel rubber system is thermo-sensitive gel.Flow process enters into step 204.
In step 204, according to definite injecting scheme and the injection rate of optimization, gel is injected after water exit interval, inject and replace slug, last steam injection.Flow process enters into step 205.
In step 205, after injection technology finishes, stewing well 3-6 days.Flow process enters into step 206.
In step 206, carry out DTEM test, test steam entry profile and horizontal segment thermal field distribution situation.Flow process finishes.
In specific embodiments of the invention 1: certain oil field, reservoir depth is 1360m, stock tank oil viscosity 21000mPa.s (50 ℃), average pore 29%, mean permeability 500md, core intersection is 8-11m, the back production water yield is 300%, and salinity is 18600-21300mg/L.This well is that well is adjusted in old liberated area, adopts accurate sand screen mode completion, has carried out steam soak and has produced, moisture always higher than 97% before measure, determines to utilize the stifled tune system of thermo-sensitive gel to carry out measure.
1) according to oil field geologic feature and exploitation present situation, carry out coarse screening.This oil reservoir meets the following conditions: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100 mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, the little 1000mg/L-100000mg/L of salinity;
2) service shaft and the offset well condition of production being analyzed, is near B target spot in conjunction with the reservoir geology profile analysis EXIT POINT of this well, and horizontal well thermal recovery DTEM test result is apart from the water outlet of B target spot 50m well section;
3), according to Physical simulation experiment, by numerical reservoir simulation method simulation steam injection amount and thermal field distribution schematic diagram as shown in Figure 3, the injection rate of optimizing thermo-sensitive gel system is 260m
3, minute three slugs inject and replace slug size is 180m
3;
4) inject steam injection 2500m
3, after injection technology finishes, stewing well 5 days;
5) carry out DTEM test, as shown in Figure 4, horizontal segment maximum temperature difference drops to 19 ℃ by 51 ℃ to testing level section thermal field distribution situation schematic diagram, shows that thermo-sensitive gel system is to reservoir plugging macropore, improves steam entry profile and has reached expection object.
Service shaft is carried out to effect trace analysis, this well steady production more than 220 day, the minimum decline 21% of comprehensive water cut, average is 11.6%, the cycle increases oily 550t, obtains good development effectiveness.
In another specific embodiment 2 of the inventor: certain oil field, reservoir depth is 1500m, stock tank oil viscosity 28500mPa.s (50 ℃), average pore 32%, mean permeability 3100md, total salinity 13254～16700mg/L, core intersection is 10-13m, having carried out steam soak produces, the back production water yield is 700%, and this well is that well is adjusted in old liberated area, adopts accurate sand screen mode completion, moisture always higher than 99% before measure, determine to utilize thermo-sensitive gel+thermosetting blocking agent to carry out measure.
1) according to oil field geologic feature and exploitation present situation, carry out coarse screening.This oil reservoir meets the following conditions: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100 mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, the little 1000mg/L-100000mg/L of salinity;
2) service shaft and the offset well condition of production are analyzed, in conjunction with the reservoir geology profile analysis EXIT POINT of this well, be near two ends water outlet A and B target spot, horizontal well thermal recovery DTEM test result is near near 50m well section water outlet 30m well section and B target spot A target spot;
3) according to Physical simulation experiment, by numerical reservoir simulation method, simulate steam injection amount and thermal field distributes, the injection rate of optimizing thermo-sensitive gel system is 300m
3, minute two slugs inject, replace slug size is 150m
3, thermosetting blocking agent injection rate is 50m
3;
4) inject steam injection 2000m
3, after injection technology finishes, stewing well 4 days;
5) again carry out DTEM test, test steam entry profile and horizontal segment thermal field distribution situation, test result shows significantly improves steam entry profile, has reached expection object.
Service shaft is carried out to effect trace analysis, this well steady production more than 180 day, the minimum decline 16% of comprehensive water cut, average is 10.8%, the cycle increases oily 480t, obtains good development effectiveness.
Claims (10)
1. the method for horizontal well thermal recovery water plugging and profile controlling, is characterized in that, the method for this horizontal well thermal recovery water plugging and profile controlling comprises:
Step 1, utilizes horizontal well thermal recovery DTEM measuring technology to determine water exit interval in conjunction with reservoir geology situation;
Step 2, simulates steam injection amount and thermal field distributes by numerical reservoir simulation method, determines injecting scheme, optimizes the injection rate of gel and blocking agent and replaces slug size; And
Step 3, according to this injecting scheme and this gel of optimization and the injection rate of this blocking agent determined, injects this gel and this blocking agent after this water exit interval, injects this replacement slug, last steam injection.
2. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, it is characterized in that, the method of this horizontal well thermal recovery water plugging and profile controlling also comprises, after step 1, calculates the injection rate of this gel and this blocking agent according to water exit interval length, Living space and reservoir parameter.
3. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, is characterized in that, the method for this horizontal well thermal recovery water plugging and profile controlling is also included in after step 3, stewing well 3-6 days; And carry out DTEM test, test steam entry profile and horizontal segment thermal field distribution situation.
4. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, it is characterized in that, the oil reservoir of applying the method for this horizontal well thermal recovery water plugging and profile controlling is: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, little 1000 mg/L-100000mg/L of salinity.
5. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, is characterized in that, this gel is thermo-sensitive gel, and this blocking agent is thermosetting blocking agent.
6. the method for horizontal well thermal recovery water plugging and profile controlling, is characterized in that, the method for this horizontal well thermal recovery water plugging and profile controlling comprises:
Step 1, utilizes horizontal well thermal recovery DTEM measuring technology to determine water exit interval in conjunction with reservoir geology situation;
Step 2, simulates steam injection amount and thermal field distributes by numerical reservoir simulation method, determines injecting scheme, optimizes the injection rate of gel and replaces slug size; And
Step 3, according to the injection rate of this gel of this injecting scheme of determining and optimization, injects this gel after this water exit interval, injects this replacement slug, last steam injection.
7. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, is characterized in that, the method for this horizontal well thermal recovery water plugging and profile controlling also comprises, after step 1, calculates the injection rate of this gel according to water exit interval length, Living space and reservoir parameter.
8. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, is characterized in that, the method for this horizontal well thermal recovery water plugging and profile controlling is also included in after step 3, stewing well 3-6 days; And carry out DTEM test, test steam entry profile and horizontal segment thermal field distribution situation.
9. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, it is characterized in that, the oil reservoir of applying the method for this horizontal well thermal recovery water plugging and profile controlling is: reservoir temperature is 40 ℃-120 ℃, ground degas oil viscosity is 100mPa.s-100000mPa.s (50 ℃), mean permeability 100mDc-10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is greater than 0.25, back production water 100%-1000%, little 1000 mg/L-100000mg/L of salinity.
10. the method for horizontal well thermal recovery water plugging and profile controlling according to claim 1, is characterized in that, this gel is thermo-sensitive gel.
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| CN114427376B (en) * | 2020-09-22 | 2024-04-26 | 中国石油化工股份有限公司 | Method for enhancing lateral drive between wells of large-bottom water reservoir |
| CN114282387A (en) * | 2021-12-29 | 2022-04-05 | 西南石油大学 | DTS-based comprehensive evaluation method for steam injection horizontal well of heavy oil reservoir |
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