CN105863587A - Method for determining alternating injection time of polymer flooding - Google Patents
Method for determining alternating injection time of polymer flooding Download PDFInfo
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- CN105863587A CN105863587A CN201610382195.XA CN201610382195A CN105863587A CN 105863587 A CN105863587 A CN 105863587A CN 201610382195 A CN201610382195 A CN 201610382195A CN 105863587 A CN105863587 A CN 105863587A
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- displacement system
- oil displacement
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- opportunity
- viscosity
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- 229920000642 polymer Polymers 0.000 title claims abstract description 31
- 238000002347 injection Methods 0.000 title claims abstract description 27
- 239000007924 injection Substances 0.000 title claims abstract description 27
- 238000000034 method Methods 0.000 title claims abstract description 26
- 238000006073 displacement reaction Methods 0.000 claims abstract description 65
- 230000000630 rising effect Effects 0.000 claims abstract description 4
- 230000035699 permeability Effects 0.000 claims description 25
- 230000015572 biosynthetic process Effects 0.000 claims description 24
- 230000008859 change Effects 0.000 claims description 10
- 239000007864 aqueous solution Substances 0.000 claims description 9
- 239000012530 fluid Substances 0.000 claims description 9
- 238000004519 manufacturing process Methods 0.000 claims description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 7
- 230000007423 decrease Effects 0.000 claims description 3
- 238000011161 development Methods 0.000 abstract description 7
- 230000000694 effects Effects 0.000 abstract description 3
- 239000007788 liquid Substances 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 35
- 238000001764 infiltration Methods 0.000 description 3
- 230000008595 infiltration Effects 0.000 description 3
- 238000011160 research Methods 0.000 description 3
- 238000010521 absorption reaction Methods 0.000 description 2
- 230000002068 genetic effect Effects 0.000 description 2
- 230000014759 maintenance of location Effects 0.000 description 2
- 238000001179 sorption measurement Methods 0.000 description 2
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000005213 imbibition Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000000126 substance 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
- 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
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
- Materials For Medical Uses (AREA)
Abstract
The invention discloses a method for determining alternating injection time of polymer flooding. The method comprises the step of determining injection time 1, injection time 2 and injection time 3 according to the changes of moisture content and shunt rate of an oil-displacement system in a high-permeability layer, wherein the injection time 1 is a corresponding period when the moisture content of output liquid reaches a certain value, the injection time 2 is a corresponding period when the shunt rate of the oil-displacement system in the high-permeability layer is suddenly changed, and the injection time 3 is a corresponding period when the shunt rate of the oil-displacement system in the high-permeability layer is in a rising trend and becomes flat. According to the method, the viscosity of a new oil-displacement system corrected to be injected in the injection time 1 is larger than that of the injected oil-displacement system, the viscosity of a new oil-displacement system corrected to be injected in the injection time 2 is smaller than that of the oil-displacement system corrected to be injected in the injection time 1, and the viscosity of a new oil-displacement system corrected to be injected in the injection time 3 is smaller than that of the oil-displacement system corrected to be injected in the injection time 2; and different oil replacement effects of chemically flooded heterogeneous reservoirs can be achieved, and the development degree of a low-permeability layer is improved.
Description
Technical field
The present invention relates to a kind of polymer flooding and replace the determination method of injection timing, belong to oil development technical field.
Background technology
For the oil reservoir that anisotropism is stronger, the injection mode of single polymers slug can invert by genetic profile, makes infiltration
Relatively low reservoir (the calling low-permeability layer in the following text) remaining oil of rate is more.Research shows, is carried out by different viscosities oil displacement system
The mode alternately injected, it is possible in the case of the constant even reduction of polymer volume, significantly improve heterogeneous reservoir
Oil displacement effect of polymer, improves the development degree of low-permeability layer.In order to determine optimum efficiency alternately, it is necessary to root
According to viscosity and the physical property on stratum of oil displacement system, select suitable oil displacement system and injection rate thereof, slug length,
The isoparametric impact of injection timing.Although oil field, state inland basin has been carried out alternately injects research, but the longest at slug
The aspects such as degree, the alternately frequency have carried out research, but the opportunity alternately injected has no that document is reported.
Summary of the invention
It is an object of the invention to provide a kind of polymer flooding and replace the determination method of injection timing, by the method for the present invention
The heterogeneous reservoir that can make enforcement chemical flooding obtains different oil displacement efficiencies, improves the development degree of low-permeability layer.
The polymer flooding that the present invention provides replaces the determination method of injection timing, is at height according to moisture content and oil displacement system
The change of the streaming rate in infiltration layer determines alternately opportunity 1, alternately opportunity 2 and alternately opportunity 3；
Described alternately opportunity 1 is the period corresponding when production fluid moisture content reaches certain value；
Described alternately opportunity 2 is the period corresponding when oil displacement system streaming rate abrupt change in described high permeability formation；
Described alternately opportunity 3 is when oil displacement system streaming rate in described high permeability formation is in rising trend and tends towards stability
Corresponding period.
In above-mentioned determination method, described high permeability formation refers to the reservoir of permeability relatively high (comparing with low-permeability layer).
In above-mentioned determination method, injected before the viscosity of the described new oil displacement system alternately changing note opportunity 1 is more than
The viscosity of described oil displacement system；
The displacement of reservoir oil of note is changed when the viscosity of the described new oil displacement system alternately changing note opportunity 2 is less than described alternately opportunity 1
The viscosity of system；
The displacement of reservoir oil of note is changed when the viscosity of the described new oil displacement system alternately changing note opportunity 3 is less than described alternately opportunity 2
The viscosity of system.
Described determine that method specifically includes following steps:
(1), after injecting oil displacement system 1 in stratum, in production fluid, moisture content rises, when moisture content rises to necessarily
Value, is alternately opportunity 1, now changes note oil displacement system 2, and the viscosity of described oil displacement system 2 is higher than described oil displacement system
The viscosity of 1；
(2) the described oil displacement system 2 streaming rate in described high permeability formation in after falling before rise change, decline with
The turning point risen is alternately opportunity 2, now changes note oil displacement system 3, and the viscosity of described oil displacement system 3 is less than described
The viscosity of oil displacement system 2；
(3) the described oil displacement system 3 streaming rate in described high permeability formation rises, when ascendant trend tends towards stability,
It is alternately opportunity 3, now changes the described oil displacement system 1 of note；
(4) step (1)-(3) are repeated, until the displacement of reservoir oil completes.
In above-mentioned determination method, described oil displacement system 1 is water；
Described oil displacement system 2 and described oil displacement system 3 are the aqueous solutions of polymers of variable concentrations.
In above-mentioned determination method, in step (1), described definite value refers to the value between 40～100%.
In above-mentioned determination method, in step (2), described decline refers to described displacement of reservoir oil body with the turning point of rising
It it is 2 streaming rates in described high permeability formation periods corresponding when being 50%～100%.
In above-mentioned determination method, in step (3), refer to the period that described ascendant trend tends towards stability described in drive
The oil systems 3 streaming rate in described high permeability formation and the streaming rate ratio amplitude of variation in low-permeability layer are less than 10% time institute
Corresponding period.
At the polymer flooding initial stage, polymer enters high permeability formation, and Adsorption And Retention wherein more, causes high permeability formation stream
Dynamic resistance increases, and is embodied on streaming rate (Fig. 1), it is simply that high permeability formation streaming rate reduces, and low-permeability layer streaming rate rises,
Along with high permeability formation resistance increases, polymer starts more entrance low-permeability layer, and the imbibition of heterogeneous reservoir is cutd open by this process
Face makes moderate progress.But, after polymer constantly enters low-permeability layer, flow resistance can be produced equally wherein, and hinder
Faster, when low-permeability layer resistance increases to a certain degree, more polymer can be again introduced into again height and ooze the growth rate of power
Layer, occurs that section inverts, and polymer is advanced by leaps and bounds in high permeability formation, and low-permeability layer development degree is low.In order to improve section reversion,
Enable low-permeability layer to a greater degree, alternately inject when low-permeability layer streaming rate arrives peak, it is possible to play notable
Improvement result.As in figure 2 it is shown, after water drive terminates, start to inject the polymer slug of high concentration, because of its concentration relatively
Height, Adsorption And Retention ability more single slug polymer is strong, produces resistance speed, at single polymers concentration slug
During injection before genetic profile reversion before hypotonic streaming rate minimum point, inject low polymer and can significantly improve fluid entry profile,
Fluid entry profile is become U-shaped by V-shape, and low-permeability layer can maintain higher liquid absorption within the longer time, improves low
The development degree of infiltration layer.
Accompanying drawing explanation
Fig. 1 is the single polymers concentration plug flow diverting rate change curve with injection rate.
Fig. 2 is that the dense polymer of height that alternately carries out opportunity determined according to the inventive method alternately injects streaming rate with injection
The change curve of amount.
Detailed description of the invention
Experimental technique used in following embodiment if no special instructions, is conventional method.
Material used in following embodiment, reagent etc., if no special instructions, the most commercially obtain.
Single polymers concentration plug flow diverting rate with the change of injection rate as it is shown in figure 1, before carrying out polymer flooding,
First carry out water drive, when in production fluid, moisture content changes polymer injection aqueous solution and carries out polymer flooding when reaching 40～100%,
The opportunity changing note is alternately opportunity 1；Aqueous solutions of polymers streaming rate in high permeability formation is in the V risen after falling before
Font, is alternately opportunity 2 on the opportunity corresponding to the turning point declined and rise, and changes note when alternately opportunity 2 viscous
The aqueous solutions of polymers that degree is little relatively before；Aqueous solutions of polymers streaming rate in high permeability formation continues to rise, and works as high permeability formation
Streaming rate is alternately opportunity 3 when being less than 10% with low-permeability layer streaming rate ratio amplitude of variation, now changes water drive into.
Use polyacrylamide SNF3640D, alternately carry out the alternately displacement of reservoir oil opportunity according to what the invention described above determined, tool
Body step is as follows:
It is filled with SNF3640D water when alternately opportunity 1 (moisture content reaches the period corresponding to 80% in production fluid)
Solution (viscosity is 34mPa.s), on alternately opportunity 2, (SNF3640D aqueous solution streaming rate in high permeability formation is 60.5%
Time corresponding period) time be filled with a kind of SNF3640D aqueous solution (viscosity is 10mPa.s), in alternately opportunity 3
(when SNF3640D aqueous solution streaming rate in high permeability formation is 4% with the shunting degree ratio amplitude of variation in low-permeability layer
Corresponding period) time inject water, the effect after alternately injection is as shown in " alternately " curve in Fig. 2.By Fig. 2
It can be seen that after method determined by according to is alternately injected, the liquid absorption of low-permeability layer is substantially than original (" not replacing " song
Line) high, i.e. the crude oil of low-permeability layer by displacement go out more, development degree is higher, and the degree of raising is two curve institutes
The area of the closed figure surrounded.
Claims (7)
1. a polymer flooding replaces the determination method of injection timing, it is characterised in that: according to production fluid moisture content and
The change of oil displacement system streaming rate in high permeability formation determines alternately opportunity 1, alternately opportunity 2 and alternately opportunity 3；
Described alternately opportunity 1 is the period corresponding when production fluid moisture content reaches certain value；
Described alternately opportunity 2 is the period corresponding when oil displacement system streaming rate abrupt change in described high permeability formation；
Described alternately opportunity 3 is when oil displacement system streaming rate in described high permeability formation is in rising trend and tends towards stability
Corresponding period.
The most according to claim 1 determine method, it is characterised in that: alternately change the new of note opportunity 1 described
The viscosity of oil displacement system more than the viscosity of described oil displacement system injected before；
The displacement of reservoir oil of note is changed when the viscosity of the described new oil displacement system alternately changing note opportunity 2 is less than described alternately opportunity 1
The viscosity of system；
The displacement of reservoir oil of note is changed when the viscosity of the described new oil displacement system alternately changing note opportunity 3 is less than described alternately opportunity 2
The viscosity of system.
The most according to claim 1 and 2 determine method, it is characterised in that: specifically include following steps:
(1), after injecting oil displacement system 1 in stratum, in production fluid, moisture content rises, when moisture content rises to necessarily
Value, is alternately opportunity 1, now changes note oil displacement system 2, and the viscosity of described oil displacement system 2 is higher than described oil displacement system
The viscosity of 1；
(2) the described oil displacement system 2 streaming rate in described high permeability formation in after falling before rise change, decline with
The turning point risen is alternately opportunity 2, now changes note oil displacement system 3, and the viscosity of described oil displacement system 3 is less than described
The viscosity of oil displacement system 2；
(3) the described oil displacement system 3 streaming rate in described high permeability formation rises, when ascendant trend tends towards stability,
It is alternately opportunity 3, now changes the described oil displacement system 1 of note；
(4) step (1)-(3) are repeated, until the displacement of reservoir oil completes.
The most according to claim 3 determine method, it is characterised in that: described oil displacement system 1 is water；
Described oil displacement system 2 and described oil displacement system 3 are the aqueous solutions of polymers of variable concentrations.
5. according to the determination method described in claim 3 or 4, it is characterised in that: in step (1), described definite value
Refer to the value between 40～100%.
6. according to the determination method according to any one of claim 3-5, it is characterised in that: in step (2), institute
Stating the turning point declined and rise and referring to the described oil displacement system 2 streaming rate in described high permeability formation is 50%～100%
Time corresponding period.
7. according to the determination method according to any one of claim 3-6, it is characterised in that: in step (3), institute
State refer to the period that ascendant trend tends towards stability the described oil displacement system 3 streaming rate in described high permeability formation with hypotonic
Period corresponding when streaming rate ratio amplitude of variation in Ceng is less than 10%.
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| CN201610382195.XA CN105863587B (en) | 2016-06-01 | 2016-06-01 | A kind of determination method of polymer flooding alternating injection timing |
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| CN201610382195.XA CN105863587B (en) | 2016-06-01 | 2016-06-01 | A kind of determination method of polymer flooding alternating injection timing |
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| CN105863587B CN105863587B (en) | 2018-10-16 |
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Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106703768A (en) * | 2016-11-29 | 2017-05-24 | 中国海洋石油总公司 | Determining method of simulating high-low-concentration polymer flooding alternating injection time |
| CN107869340A (en) * | 2016-09-23 | 2018-04-03 | 中国石油化工股份有限公司 | The system of selection on thick oil well bore viscosity reduction opportunity |
| CN109852362A (en) * | 2018-12-28 | 2019-06-07 | 中国海洋石油集团有限公司 | The double slug profile control agents and its method for implanting that heterogeneous reservoir predominant pathway controls after a kind of poly- drive |
| CN111322054A (en) * | 2018-12-17 | 2020-06-23 | 中国石油天然气股份有限公司 | Three-three combined excavation and potential optimization mining method for sandstone oil reservoir in chemical flooding stage |
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Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107869340A (en) * | 2016-09-23 | 2018-04-03 | 中国石油化工股份有限公司 | The system of selection on thick oil well bore viscosity reduction opportunity |
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| CN106703768B (en) * | 2016-11-29 | 2019-02-12 | 中国海洋石油集团有限公司 | A kind of determination method of simulation high-concentration and low-concentration polymer flooding alternating injection timing |
| CN111322054A (en) * | 2018-12-17 | 2020-06-23 | 中国石油天然气股份有限公司 | Three-three combined excavation and potential optimization mining method for sandstone oil reservoir in chemical flooding stage |
| CN109852362A (en) * | 2018-12-28 | 2019-06-07 | 中国海洋石油集团有限公司 | The double slug profile control agents and its method for implanting that heterogeneous reservoir predominant pathway controls after a kind of poly- drive |
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