CN103527161B - The method of horizontal well thermal recovery water plugging and profile controlling - Google Patents
The method of horizontal well thermal recovery water plugging and profile controlling Download PDFInfo
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Abstract
The present invention provides a kind of method of horizontal well thermal recovery water plugging and profile controlling, and the method for the horizontal well thermal recovery water plugging and profile controlling includes：Step 1, water exit interval is determined using horizontal well thermal recovery DTEM measuring technology combination reservoir geology situation；Step 2, steam injection and thermo parameters method are simulated by numerical reservoir simulation method, determines injecting scheme, optimized the injection rate of gel and blocking agent and replace slug size；And step 3, according to the injecting scheme of determination and the gel of optimization and the injection rate of the blocking agent, after the gel and the blocking agent are injected into the water exit interval, inject the replacement slug, last steam injection.The method of the horizontal well thermal recovery water plugging and profile controlling utilizes temperature field selective shut-off high permeability zone, enters steam and does not employ oil reservoir, improves the steam entry profile of reservoir, so as to reach the purpose of economical and efficient exploitation High water cut horizontal well thermal recovery.
Description
Technical field
The present invention relates to technical field of petroleum extraction, especially relates to a kind of method of horizontal well thermal recovery water plugging and profile controlling.
Background technology
With drilling well and the raising of completion technique, horizontal well thermal recovery is in oil field using more and more.Horizontal well thermal recovery water
Flat segment length, drainage area is big, and the onlap of steam can be utilized to improve viscous crude well yield, is that current old area is taped the latent power and low-grade thick
The dominant technology of oily oil reservoir development, and the major way of heavy crude reservoir thermal recovery Productivity Construction, High water cut are to influence thermal recovery level
The horizontal well thermal recovery of the subject matter of well development effect, especially sieve tube completion, once comprehensive water cut raises, there is presently no have
The water plugging and profile controlling technological measure of effect.At present, the stifled conditioning technology that scene uses is big in the prevalence of engineering risk, and cost is high, closure
Intensity is weak, the problems such as poor selectivity.So there is an urgent need to research and develop to can effectively solve the problem that thermal recovery level for oil field development and produce reality
The production practice of well High water cut problem.For this we have invented a kind of method of new horizontal well thermal recovery water plugging and profile controlling, solve
Above technical problem.
The content of the invention
Gel is injected to improve High water cut horizontal well thermal recovery development effectiveness into stratum it is an object of the invention to provide one kind
Horizontal well thermal recovery water plugging and profile controlling method.
The purpose of the present invention can be achieved by the following technical measures：The method of horizontal well thermal recovery water plugging and profile controlling, the thermal recovery
The method of water plugging of horizontal well profile control includes：Step 1, horizontal well thermal recovery DTEM measuring technology combination reservoir geology situation is utilized
Determine water exit interval；Step 2, steam injection and thermo parameters method are simulated by numerical reservoir simulation method, it is determined that injection side
Case, optimize the injection rate of gel and blocking agent and replace slug size；And step 3, according to injecting scheme of determination and excellent
The gel and the injection rate of the blocking agent changed, after the gel and the blocking agent are injected into the water exit interval, inject the replacement slug, most
Steam injection afterwards.
The purpose of the present invention can be also achieved by the following technical measures：
The method of the horizontal well thermal recovery water plugging and profile controlling also includes, after step 1, according to water exit interval length, Living space
And reservoir parameter calculates the injection rate of the gel and the blocking agent.
After the method for the horizontal well thermal recovery water plugging and profile controlling is additionally included in step 3, well is boiled in a covered pot over a slow fire 3-6 days；And carry out DTEM
Test, test steam entry profile and horizontal segment thermo parameters method situation.
Oil reservoir using the method for the horizontal well thermal recovery water plugging and profile controlling is：Reservoir temperature is 40 DEG C -120 DEG C, ground degassing
Oil viscosity is 100mPa.s-100000mPa.s (50 DEG C), mean permeability 100mDc-10000mDc, core intersection 5m-50m,
Remaining oil saturation 0.2-0.8, oil reservoir average pore are more than 0.25, back production water 100%-1000%, small 1000 mg/ of salinity
L-100000mg/L。
The gel is thermo-sensitive gel, and the blocking agent is thermosetting blocking agent.
The purpose of the present invention can be also achieved by the following technical measures：The method of horizontal well thermal recovery water plugging and profile controlling, it is special
Sign is that the method for the horizontal well thermal recovery water plugging and profile controlling includes：
Step 1, water exit interval is determined using horizontal well thermal recovery DTEM measuring technology combination reservoir geology situation；
Step 2, steam injection and thermo parameters method are simulated by numerical reservoir simulation method, determines injecting scheme, it is excellent
Change the injection rate of gel and replace slug size；And
Step 3, according to the injection rate of the injecting scheme of determination and the gel of optimization, the gel is injected into the water-yielding stratum
Duan Hou, inject the replacement slug, last steam injection.
The purpose of the present invention can be also achieved by the following technical measures：
The method of the horizontal well thermal recovery water plugging and profile controlling also includes, after step 1, according to water exit interval length, Living space
And reservoir parameter calculates the injection rate of the gel.
After the method for the horizontal well thermal recovery water plugging and profile controlling is additionally included in step 3, well is boiled in a covered pot over a slow fire 3-6 days；And carry out DTEM
Test, test steam entry profile and horizontal segment thermo parameters method situation.
Oil reservoir using the method for the horizontal well thermal recovery water plugging and profile controlling is：Reservoir temperature is 40 DEG C -120 DEG C, ground degassing
Oil viscosity is 100mPa.s-100000mPa.s (50 DEG C), mean permeability 100mDc-10000mDc, core intersection 5m-50m,
Remaining oil saturation 0.2-0.8, oil reservoir average pore are more than 0.25, back production water 100%-1000%, small 1000 mg/ of salinity
L-100000mg/L。
The gel is thermo-sensitive gel.
The method of horizontal well thermal recovery water plugging and profile controlling in the present invention, it is under cryogenic low viscosity flow by injecting gel
Body, high permeability zone is preferentially entered, using reservoir temperature field, realize selective shut-off, change Reservoir Seepage passage, enter steam
Oil reservoir is not employed, improves the steam entry profile of reservoir；In addition, can also be sealed by injecting heat curing-type blocking agent, strengthen gel rubber system
Plugging strength, so as to reach the purpose of economical and efficient exploitation High water cut horizontal well thermal recovery.Increased by the technological measure individual well cycle
Oily 400t or so, reduce aqueous 10% or so.
Brief description of the drawings
Fig. 1 is the flow chart of a specific embodiment of the method for the 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 the horizontal well thermal recovery water plugging and profile controlling of the present invention；
Fig. 3 is that numerical reservoir simulation method simulates steam injection and thermo parameters method signal in one embodiment of the invention
Figure；
Fig. 4 is testing level section thermo parameters method situation schematic diagram in one embodiment of the invention.
Embodiment
For enable the present invention above and other objects, features and advantages become apparent, it is cited below particularly go out preferable implementation
Example, and coordinate institute's accompanying drawings, it is described in detail below.
As shown in figure 1, Fig. 1 is the flow of a specific embodiment of the method for the horizontal well thermal recovery water plugging and profile controlling of the present invention
Figure.Wherein, the oil reservoir applicable elements for horizontal well thermal recovery water plugging and profile controlling new method are：Reservoir temperature is 40 DEG C -120 DEG C, ground
Emaciated face gas and oil viscosity is 100 mPa.s-100000mPa.s (50 DEG C), mean permeability 100mDc -10000mDc, core intersection
5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore is more than 0.25, back production water 100%-1000%, and salinity is small
1000mg/L-100000mg/L。
In step 101, water exit interval is determined using horizontal well thermal recovery DTEM measuring technology combination reservoir geology situation.
Particularly, service shaft and the offset well condition of production are analyzed, according to horizontal well thermal recovery DTEM test result, knot
The reservoir geology overview for closing the well determines water exit interval.Flow enters step 102.
In step 102, according to water exit interval length, Living space and the injection rate of reservoir parameter calculated for gel and blocking agent.
Flow enters step 103.
In step 103, according to Physical simulation experiment, steam injection and temperature are simulated by numerical reservoir simulation method
Field distribution is spent, determines injecting scheme, optimizes the injection rate of gel and blocking agent and replaces slug size.In embodiment, this is solidifying
Colloid system is thermo-sensitive gel, and the blocking agent is thermosetting blocking agent.In one embodiment, it is more than 3000mDc in Reservoir Permeability, produces
During back production water be more than 500% when use thermosetting blocking agent because being not so good as thermosetting in view of the plugging strength of thermo-sensitive gel
Type blocking agent, and the heatproof of heat curing-type blocking agent, also superior to thermo-sensitive gel, but from the point of view of economy, thermo-sensitive gel is compared with heat curing-type
Blocking agent has advantage.Flow enters step 104.
In step 104, according to the injecting scheme of determination and the injection rate of optimization, by stifled tune system（Gel and blocking agent）Injection
After water exit interval, injection replaces slug, last steam injection.Flow enters step 105.
In step 105, after injection technology terminates, well is boiled in a covered pot over a slow fire 3-6 days.Flow enters step 106.
In step 106, DTEM test is carried out, tests steam entry profile and horizontal segment thermo parameters method situation.Flow knot
Beam.
Fig. 2 is the flow chart of the another specific embodiment of the method for the horizontal well thermal recovery water plugging and profile controlling of the present invention.Wherein, use
It is in the oil reservoir applicable elements of horizontal well thermal recovery water plugging and profile controlling new method：Reservoir temperature is 40 DEG C -120 DEG C, and ground degassing oil is viscous
Spend for 100 mPa.s-100000mPa.s (50 DEG C), mean permeability 100mDc -10000mDc, core intersection 5m-50m, remain
Excess oil saturation degree 0.2-0.8, oil reservoir average pore are more than 0.25, back production water 100%-1000%, the small 1000mg/L- of salinity
100000mg/L。
In step 201, water exit interval is determined using horizontal well thermal recovery DTEM measuring technology combination reservoir geology situation.
Particularly, service shaft and the offset well condition of production are analyzed, according to horizontal well thermal recovery DTEM test result, knot
The reservoir geology overview for closing the well determines water exit interval.Flow enters step 202.
In step 202, according to the injection rate of water exit interval length, Living space and reservoir parameter calculated for gel.Flow is entered
Enter to step 203.
In step 203, according to Physical simulation experiment, steam injection and temperature are simulated by numerical reservoir simulation method
Field distribution is spent, determines injecting scheme, optimizes the injection rate of gel and replaces slug size.In embodiment, the gel rubber system
For thermo-sensitive gel.Flow enters step 204.
In step 204, according to the injecting scheme of determination and the injection rate of optimization, after gel is injected into water exit interval, inject
Replace slug, last steam injection.Flow enters step 205.
In step 205, after injection technology terminates, well is boiled in a covered pot over a slow fire 3-6 days.Flow enters step 206.
In step 206, DTEM test is carried out, tests steam entry profile and horizontal segment thermo parameters method situation.Flow knot
Beam.
In the specific embodiment 1 of the present invention：Certain oil field, reservoir depth 1360m, stock tank oil viscosity
21000mPa.s (50 DEG C), average pore 29%, mean permeability 500md, core intersection 8-11m, back production water are
300%, salinity 18600-21300mg/L.The well is that old area adjusts well, using accurate sand screen mode completion, has been carried out
Steam soak production is crossed, it is aqueous always above 97% before measure, determine that blocking up tune system using thermo-sensitive gel carries out measure.
1）According to oil field geologic feature and exploitation actuality, coarse sizing is carried out.The oil reservoir meets following condition：Reservoir temperature is
40 DEG C -120 DEG C, ground degassing oil viscosity is 100 mPa.s-100000mPa.s (50 DEG C), mean permeability 100mDc -
10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore are more than 0.25, back production water
100%-1000%, the small 1000mg/L-100000mg/L of salinity；
2）Service shaft and the offset well condition of production are analyzed, with reference to the reservoir geology profile analysis EXIT POINT of the well
Near B target spots, horizontal well thermal recovery DTEM test result is distance B target spot 50m well section water outlets；
3）According to Physical simulation experiment, steam injection is simulated by numerical reservoir simulation method as shown in Figure 3
And thermo parameters method schematic diagram, the injection rate of optimization thermo-sensitive gel system is 260m3, point three slugs inject and replacement slug size
For 180m3；
4）Inject steam injection 2500m3, after injection technology terminates, boil in a covered pot over a slow fire well 5 days；
5）DTEM test is carried out, testing level section thermo parameters method situation schematic diagram is as shown in figure 4, horizontal segment is maximum
The temperature difference drops to 19 DEG C by 51 DEG C, shows that thermo-sensitive gel system to reservoir plugging macropore, improves steam entry profile and reached expection
Purpose.
Effect trace analysis is carried out to service shaft, the well steady production more than 220 days, comprehensive water cut is minimum to decline 21%, averagely
It is worth for 11.6%, the cycle increases oily 550t, obtains good development effectiveness.
In the another specific embodiment 2 of the present inventor：Certain oil field, reservoir depth 1500m, stock tank oil viscosity
28500mPa.s (50 DEG C), average pore 32%, mean permeability 3100md, 13254~16700mg/L of total salinity, oil reservoir
Thickness is 10-13m, has carried out steam soak production, and back production water is 700%, and the well is that old area adjusts well, using precision
Sand screen mode completion, it is aqueous always above 99% before measure, determine to carry out measure using thermo-sensitive gel+thermosetting blocking agent.
1）According to oil field geologic feature and exploitation actuality, coarse sizing is carried out.The oil reservoir meets following condition：Reservoir temperature is
40 DEG C -120 DEG C, ground degassing oil viscosity is 100 mPa.s-100000mPa.s (50 DEG C), mean permeability 100mDc -
10000mDc, core intersection 5m-50m, remaining oil saturation 0.2-0.8, oil reservoir average pore are more than 0.25, back production water
100%-1000%, the small 1000mg/L-100000mg/L of salinity；
2）Service shaft and the offset well condition of production are analyzed, with reference to the reservoir geology profile analysis EXIT POINT of the well
For both ends water outlet near A and B target spots, horizontal well thermal recovery DTEM test result is that nearby 30m well sections and B target spots are attached for A target spots
Nearly 50m well section water outlets；
3）According to Physical simulation experiment, steam injection and temperature field point are simulated by numerical reservoir simulation method
Cloth, the injection rate of optimization thermo-sensitive gel system is 300m3, it is 150m to be divided to the injection of two slugs, replace slug size3, thermosetting blocking agent
Injection rate is 50m3；
4）Inject steam injection 2000m3, after injection technology terminates, boil in a covered pot over a slow fire well 4 days；
5）DTEM test is carried out again, tests steam entry profile and horizontal segment thermo parameters method situation, test result show
Show and significantly improve steam entry profile, reached expected purpose.
Effect trace analysis is carried out to service shaft, the well steady production more than 180 days, comprehensive water cut is minimum to decline 16%, averagely
It is worth for 10.8%, the cycle increases oily 480t, obtains good development effectiveness.
Claims (2)
1. the method for horizontal well thermal recovery water plugging and profile controlling, it is characterised in that the method for the horizontal well thermal recovery water plugging and profile controlling includes：
Oil reservoir applicable elements for the method for horizontal well thermal recovery water plugging and profile controlling are：Reservoir temperature is 40 DEG C -120 DEG C, ground emaciated face
The viscosity that 50 DEG C of gas and oil is 100 mPa.s-100000mPa.s, mean permeability 100mDc -10000mDc, core intersection 5m-
50m, remaining oil saturation 0.2-0.8, oil reservoir average pore are more than 0.25, back production water 100%-1000%, salinity 1000mg/
L-100000mg/L；
In step 101, service shaft and the offset well condition of production are analyzed, is tested and tied according to horizontal well thermal recovery DTEM
Fruit, water exit interval is determined with reference to the reservoir geology overview of the well；
In step 102, according to water exit interval length, Living space and the injection rate of reservoir parameter calculated for gel and blocking agent；
In step 103, according to Physical simulation experiment, steam injection and temperature field are simulated by numerical reservoir simulation method
Distribution, injecting scheme is determined, optimize the injection rate of gel and blocking agent and replace slug size；The gel is thermo-sensitive gel, should
Blocking agent is thermosetting blocking agent；It is more than 3000mDc in Reservoir Permeability, thermosetting is used when back production water is more than 500% in production process
Blocking agent；
In step 104, according to the injecting scheme of determination and the injection rate of optimization, after stifled tune system is injected into water exit interval, inject
Replace slug, last steam injection；
In step 105, after injection technology terminates, well is boiled in a covered pot over a slow fire 3-6 days；
In step 106, DTEM test is carried out, tests steam entry profile and horizontal segment thermo parameters method situation.
2. the method for horizontal well thermal recovery water plugging and profile controlling, it is characterised in that the method for the horizontal well thermal recovery water plugging and profile controlling includes：
Oil reservoir applicable elements for the method for horizontal well thermal recovery water plugging and profile controlling are：Reservoir temperature is 40 DEG C -120 DEG C, ground emaciated face
50 DEG C of viscosity of gas and oil are 100 mPa.s-100000mPa.s, mean permeability 100mDc -10000mDc, core intersection 5m-
50m, remaining oil saturation 0.2-0.8, oil reservoir average pore are more than 0.25, back production water 100%-1000%, salinity 1000mg/
L-100000mg/L；
In step 201, service shaft and the offset well condition of production are analyzed, is tested and tied according to horizontal well thermal recovery DTEM
Fruit, water exit interval is determined with reference to the reservoir geology overview of the well；
In step 202, according to the injection rate of water exit interval length, Living space and reservoir parameter calculated for gel；
In step 203, according to Physical simulation experiment, steam injection and temperature field are simulated by numerical reservoir simulation method
Distribution, determines injecting scheme, optimizes the injection rate of gel and replaces slug size, the gel is thermo-sensitive gel；
In step 204, according to the injecting scheme of determination and the injection rate of optimization, after gel is injected into water exit interval, injection replaces
Slug, last steam injection；
In step 205, after injection technology terminates, well is boiled in a covered pot over a slow fire 3-6 days；
In step 206, DTEM test is carried out, tests steam entry profile and horizontal segment thermo parameters method situation.
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| CN105089614B (en) * | 2014-05-08 | 2023-07-07 | 中国石油化工股份有限公司 | Water content tester for thermal recovery horizontal well |
| CN104060985B (en) * | 2014-06-16 | 2016-05-25 | 中国地质大学（北京） | A kind of stratified deposit profile control and water plugging blocking agent penetration depth method of testing and system |
| CN105443094B (en) * | 2014-07-31 | 2018-04-10 | 中国石油化工股份有限公司 | A kind of multichannel reservoir model of heavy crude heat extraction well to be onstructed and application |
| CN105443095B (en) * | 2014-07-31 | 2018-04-10 | 中国石油化工股份有限公司 | A kind of single channel reservoir model of heavy crude heat extraction well to be onstructed and application |
| CN104405350B (en) * | 2014-10-23 | 2017-03-08 | 中国石油天然气股份有限公司 | Chemical profile control method for horizontal well |
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| CN105525890B (en) * | 2015-11-24 | 2019-01-08 | 中国石油化工股份有限公司 | Method for sieve tube completion water plugging of horizontal well |
| CN105804714A (en) * | 2016-04-01 | 2016-07-27 | 中国石油化工股份有限公司 | Production-increasing method adopting combination of in-situ gas generation and water plugging technology |
| CN111950755B (en) * | 2019-05-16 | 2024-05-03 | 中国石油天然气股份有限公司 | Vertical well nitrogen foam polymer gel-assisted superheated steam throughput parameter optimization method |
| 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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| US3669188A (en) * | 1970-07-29 | 1972-06-13 | Shell Oil Co | Heat-guided hydroxide plugging |
| US4903768A (en) * | 1989-01-03 | 1990-02-27 | Mobil Oil Corporation | Method for profile control of enhanced oil recovery |
| US4950698A (en) * | 1989-01-03 | 1990-08-21 | Mobil Oil Corporation | Composition for selective placement of polymer gels for profile control in thermal oil recovery |
| CN1464173A (en) * | 2002-06-14 | 2003-12-31 | 中国石油天然气股份有限公司 | Modified tannin extract gel water plugging technology suitable for high-temperature high-salt oil reservoir |
| CN102182421A (en) * | 2011-03-30 | 2011-09-14 | 中国石油天然气股份有限公司 | Horizontal well liquid bridge plug segmented water plugging method |
| CN202284472U (en) * | 2011-10-25 | 2012-06-27 | 中国石油化工股份有限公司 | Differential well temperature and pressure tester for thermal recovery horizontal well |
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