CN104975826A - Method for improving recovery ratio of super heavy oil reservoir - Google Patents
Method for improving recovery ratio of super heavy oil reservoir Download PDFInfo
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- CN104975826A CN104975826A CN201410131970.5A CN201410131970A CN104975826A CN 104975826 A CN104975826 A CN 104975826A CN 201410131970 A CN201410131970 A CN 201410131970A CN 104975826 A CN104975826 A CN 104975826A
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Abstract
The invention provides a method for improving the recovery ratio of a super heavy oil reservoir. The method for improving the recovery ratio of the super heavy oil reservoir comprises the following steps of: 1, preheating two horizontal wells in parallel distribution; 2, injecting steam into the upper part horizontal well, and maintaining the original stratum pressure in the lower part horizontal well for production; 3, simultaneously injecting steam, carbon dioxide and viscosity reducers into an oil layer through the upper part horizontal well, and maintaining the original stratum pressure in the lower part horizontal well for production; and 4, stopping the injection of the carbon dioxide and the viscosity reducers, continuously injecting the steam into the upper part horizontal well and maintaining continuous production of the lower part horizontal well. The method for improving the recovery ratio of the super heavy oil reservoir has the advantages that the viscosity of crude oil is greatly reduced; the heat loss of top and bottom cover layers is reduced; the steam enthalpy is improved; the elasticity energy of the stratum and fluid is increased; the flow seeping capability in near bore zones is improved; and the crude oil is recovered through the gravity effect so as to improve the recovery ratio of the super heavy oil reservoir.
Description
Technical field
The present invention relates to oil field development technical field, particularly relate to a kind of method utilizing steam+thinner+carbon dioxide assisted gravity drainage to improve super-thick oil reservoir recovery efficiency.
Background technology
Viscous crude oil in place 6.4 × 10 verified at present by Shengli Oil Field
8t, wherein eastern oil region verifies viscous crude oil in place 5.89 × 10
8t, employs 4.69 × 10 at present
8t; Western oily district finds spring breeze, light of spring oil field in succession, verifies oil in place 5128 × 10
4t, employs 2471 × 10 at present
4t.Along with applying of new theory and new technology, at present, the annual production sustainable growth of Shengli Viscous Crude Oil, 2012 annual productions reach 475 × 10
4t is one of main force position of Shengli Oil Field stable yields volume increase.
Triumph light of spring oil field, western oily district reports control and prognostic reserves 5,333 ten thousand tons for 2011, but substantially cannot employ with prior art, mainly due to:
1, viscosity of crude is very big, and under formation temperature, (23 DEG C) degassed crude viscosity is close to 2000 × 10
4mPas, belongs to super―heavy oil oil reservoir.Conventional steam is handled up because steam injection filtrational resistance is large, and heating radius is little, cannot break through production capacity.
2, core intersection little (10-25m), is in the lower limit standard (15m) of conventional steam assisted gravity drainage techniques, and steam injection causes top bottom layer heat waste large, and the vapor chamber volume of formation is little, affects development effectiveness.
For such super―heavy oil oil reservoir, once the multiple production techniques such as nitrogen assists straight well steam soak, straight well steam soak assisted by thinner, straight well steam soak assisted by nitrogen+thinner, nitrogen auxiliary water horizontal well steam soak, nitrogen+thinner auxiliary water horizontal well steam soak were carried out, but all because viscosity of crude is high, development effectiveness is poor and cannot effectively employ.The external ripe super―heavy oil oil reservoir development technology of investigation, mainly contains steam assisted gravity drainage techniques (SAGD).This technology is particularly suitable for exploiting has certain core intersection and the very high super―heavy oil oil reservoir of viscosity of crude or natural asphalt.This technology in Canadian UTF trial zone, Surmount oil field, East Senlac oil field, multiple field use such as Makay River oil field, obtain huge success, recovery ratio can reach 50%-60%.
But the reservoir oil layer physical property of external enforcement SAGD is good, continuous core intersection is large, and oil reservoir homogenieity is good, and vertical permeability is large, and viscosity of crude is less than 500 × 10
4mPas.Domestic light of spring oil-field thick-oil reservoir condition differs comparatively large with external reservoir condition, continuous core intersection is little, not only causes Action of Gravity Field little, and due to upper and lower country rock heat waste increase.Light of spring oil field non-homogeneity is larger, and horizontal permeability is 41 ~ 1790 × 10
-3μm
2, lower permeability and stronger Reservoir Heterogeneity can affect the lateral spread of the steam rate of climb and vapor chamber, affect development effectiveness.In addition, oil viscosity is very big, close to 2000 × 10
4mPas, much larger than external similar oil reservoir, cause steam injection filtrational resistance large, heating radius is little, and conventional SAGD development technique is still difficult to effectively employ the so large oil reservoir of viscosity.
Explore the cost-effective development scheme of such oil reservoir, improve reserves exploitation rate and recovery ratio, meet the needs of the growing energy demand of people and the guarantee national economic development, be of great immediate significance.We have invented a kind of method of raising super-thick oil reservoir recovery efficiency newly for this reason, solve above technical problem.
Summary of the invention
The object of this invention is to provide a kind of method utilizing the raising super-thick oil reservoir recovery efficiency of steam+thinner+carbon dioxide assisted gravity drainage intensified oil reduction.
Object of the present invention realizes by following technical measures: the method improving super-thick oil reservoir recovery efficiency, and the method for this raising super-thick oil reservoir recovery efficiency comprises: step 1, and the horizontal well of two mouthfuls of parallel distributions is carried out preheating; Step 2, injects steam to top horizontal well, and lower horizontal well keeps original formation pressure to produce; Step 3, injects oil reservoir by upper water horizontal well by steam, carbon dioxide and thinner simultaneously, and lower horizontal well keeps original formation pressure to produce; And step 4, stop carbon dioxide injection and thinner, continue to inject steam to top horizontal well, lower horizontal well continues to produce.
Object of the present invention also realizes by following technical measures:
In step 1, in heavy crude reservoir oil reservoir, dispose about 2 mouthfuls just to parallel level distribution well, position is bottom oil reservoir, and two mouthfuls of wells keep certain distance, adopts steam injection cyclic preheat technology to carry out preheating.
In step 1, preheating time is 3-4 month.
In step 1, two mouthfuls of water horizontal wells all adopt double tube structure, wherein, the steam injection of long oil pipe, steam injection rate remains on 50-80t/d; Short oil pipe stable bottom hole pressure discharge opeing simultaneously, upper water horizontal well is a little more than lower horizontal well, and pressure reduction is 0.1MPa-0.2MPa.
In step 2, in top horizontal well long oil pipe and short oil pipe, inject well head steam quality is continuously the steam of 90% simultaneously, steam injection rate 100-150t/d.
In step 3, steam is injected continuously by upper water horizontal well long oil pipe, and well head steam quality is 90%, steam injection rate 80-120t/d; Thinner is injected by short oil pipe, and implantation quality concentration is 10-30%, and injection rate is at 0.4-0.8t/h; Carbon dioxide is injected by casing annulus, injection rate 120-180Nm
3/ h.
In step 2, the steam injection time is 1-3 month.
In step 3, steam, carbon dioxide and thinner are injected oil reservoir by upper water horizontal well simultaneously, injects 20-30d continuously.
In step 4, lower horizontal well continues to produce 30-60d, and working system remains unchanged.
The method of this raising super-thick oil reservoir recovery efficiency also comprises, and after step 4, repeats step 3 and step 4, to improve super-thick oil reservoir recovery efficiency.
The present invention provides a kind of new method for super―heavy oil oil reservoir development improves oil recovery factor, and be applicable to oil reservoir buried depth and be less than 1000m, oil reservoir continuous effective thickness is not less than 15m, and under reservoir condition, degassed crude viscosity is greater than 20 × 10
4the oil reservoir of mPas.A kind of method improving super-thick oil reservoir recovery efficiency in the present invention, due to the vapor chamber temperatures as high more than 300 DEG C formed, the thinner of use must be high temperature resistant.The present invention is the elastic energy significantly reducing viscosity of crude by adding steam+thinner+carbon dioxide, reduce top bottom layer heat waste, improve steam enthalpy, increase stratum and fluid, improve near wellbore zone percolation ability, and rely on the method for the raising super-thick oil reservoir recovery efficiency of Action of Gravity Field crude oil extraction.
Utilize thinner effectively the colloid in super―heavy oil, asphalitine macromolecular can be broken into Small molecular aggregation, and this process is irreversible, reaches the effect of viscosity reduction.In addition, thinner can also reduce oil water interfacial tension, improves displacement efficiency.
Carbon dioxide can be gathered in top and the edge of vapor chamber, reduces the heat waste of vapor chamber and cap rock, extenuates steam-condensation speed, and then contribute to the expansion of vapor chamber.Carbon dioxide can with in-place oil contact lysis, crude oil volume is significantly expanded, increases stratum elastic energy, be conducive to increase yield.In addition, carbon dioxide also has certain viscosity reduction effect and removes near wellbore zone contamination and plugging, and dredging oil flow channel, serves the effect of good suggestions for improvement.
The compound synergy of thinner and carbon dioxide is more conducive to improving steam injection quality, reduces viscosity of crude, suggestions for improvement.This intensified oil reduction method, gives full play to the Action advantage of each key element, realizes compound synergy, and then realizes effectively employing of super―heavy oil oil reservoir, realizes the recovery ratio increasing substantially such oil reservoir.
Accompanying drawing explanation
Fig. 1 is the flow chart of a specific embodiment of the method for raising super-thick oil reservoir recovery efficiency of the present invention;
Fig. 2 is warm-up phase model schematic in a specific embodiment of the present invention;
Fig. 3 is production phase model schematic in a specific embodiment of the present invention.
Detailed description of the invention
For making above and other object of the present invention, feature and advantage can become apparent, cited below particularly go out preferred embodiment, and coordinate institute's accompanying drawings, be described in detail below.
As shown in Figure 1, Fig. 1 is the flow chart of a specific embodiment of the method for raising super-thick oil reservoir recovery efficiency of the present invention.
In step 101, the horizontal well of two mouthfuls of parallel distributions is carried out preheating.In heavy crude reservoir oil reservoir, dispose about 2 mouthfuls just to parallel level distribution well, position is bottom oil reservoir, and two mouthfuls of wells keep certain distance.Adopt steam injection cyclic preheat technology.Two mouthfuls of water horizontal wells all adopt double tube structure.Wherein, the steam injection of long oil pipe, steam injection rate remains on 50-80t/d; Short oil pipe stable bottom hole pressure discharge opeing simultaneously, upper water horizontal well is a little more than lower horizontal well, and pressure reduction is 0.1MPa-0.2MPa.3-4 month preheating time.Fig. 2 represents step 101 warm-up phase schematic diagram, vapor chamber is produced respectively by upper and lower horizontal well steam injection cyclic preheat, because upper level well stream pressure is higher than lower horizontal well, upper water horizontal well vapor chamber is developed downwards, upper water horizontal well vapor chamber upwards develops, after two vapor chamber realize connection, preheating success.Flow process enters into step 102.
In step 102, inject steam to top horizontal well, bottom producing well keeps original formation pressure to produce.In one embodiment, in top horizontal well long oil pipe and short oil pipe, inject well head steam quality is continuously the steam of 90% simultaneously, steam injection rate 100-150t/d, steam injection time 1-3 month.Flow process enters into step 103.
In step 103, steam, carbon dioxide and thinner are injected oil reservoir by upper water horizontal well simultaneously, bottom producing well keeps original formation pressure to produce.In one embodiment, steam, carbon dioxide and thinner are injected oil reservoir by upper water horizontal well simultaneously, injects 20-30d continuously.Wherein, steam is injected continuously by upper water horizontal well long oil pipe, and well head steam quality is 90%, steam injection rate 80-120t/d; Thinner is injected by short oil pipe, and implantation quality concentration is 10-30%, and injection rate is at 0.4-0.8t/h; Carbon dioxide is injected by casing annulus, injection rate 120-180Nm
3/ h.Flow process enters into step 104.
In step 104, stop carbon dioxide injection and thinner, continue to inject steam to top horizontal well, lower horizontal well continues to produce 30-60d, and working system remains unchanged.Flow process terminates.
Fig. 3 represents step 102-104 production phase schematic diagram.Steam upwards and sideways expansion, progressively forms vaporium.Near top of oil horizon, crude oil under the viscosity reduction heat-blocking action of steam and carbon dioxide, along steam chamber edge to oil reservoir lower flow.Meanwhile, near top steam injection well, due to the acting in conjunction of steam, carbon dioxide and thinner, viscosity of crude declines to a great extent, crude oil under gravity with together extraction in condensation flow to bottom producing well.
In one embodiment, after step 104, step 103-104 is repeated, to improve super-thick oil reservoir recovery efficiency.
In an application specific embodiment of the present invention, include following steps:
(1) preparation:
Dispose horizontal well 2 mouthfuls, upper water horizontal well 300 m, lower horizontal well 300m, two mouthfuls of well fore-and-aft distance 5m.Every mouthful of well adopts length insulated tubing pipe string technology.
(2) warm-up phase:
A, in 2 mouthfuls of water horizontal wells long oil pipe inject steam, steam injection speed 70t/d, well head steam injection mass dryness fraction remains on more than 90%.
B, short oil pipe stable bottom hole pressure production discharge opeing.
C, top produce well stream pressure for 3.4MPa, and bottom produces well stream pressure 3.2MPa.
D, preheating time 90d.
(3) production phase:
A, 2 mouthfuls of producing wells stop steam injection discharge opeing.
B, in top horizontal well long oil pipe and short oil pipe, simultaneously continuously inject well head steam quality be the steam of 90%, steam injection rate 100t/d, 1 month steam injection time.Bottom producing well keeps flowing bottomhole pressure (FBHP) 3.5MPa to produce.
C, steam, carbon dioxide and thinner are injected oil reservoir by upper water horizontal well simultaneously, inject 20d continuously.Wherein, steam is injected continuously by upper water horizontal well long oil pipe, and well head steam quality is 90%, steam injection rate 100t/d; Thinner is injected by short oil pipe, and implantation quality concentration is 10%, and injection rate is at 0.6t/h; Carbon dioxide is injected by casing annulus, injection rate 150Nm
3/ h; Bottom producing well keeps flowing bottomhole pressure (FBHP) 3.5MPa to produce.
D, stopping carbon dioxide injection and thinner, continue to inject steam to top horizontal well, lower horizontal well continues to produce 40d, and working system remains unchanged.
E, repetition step C and D.
In application another specific embodiment of the present invention, comprise the following steps:
(1) preparation:
Dispose horizontal well 2 mouthfuls, upper water horizontal well 500m, lower horizontal well 500m, two mouthfuls of well fore-and-aft distance 5m.Every mouthful of well adopts length insulated tubing pipe string technology.
(2) warm-up phase:
A, in 2 mouthfuls of water horizontal wells long oil pipe inject steam, steam injection speed 80t/d, well head steam injection mass dryness fraction remains on more than 90%.
B, short oil pipe stable bottom hole pressure production discharge opeing.
C, top produce well stream pressure for 3.5MPa, and bottom produces well stream pressure 3.3MPa.
D, preheating time 120d.
(3) production phase:
A, 2 mouthfuls of producing wells stop steam injection discharge opeing.
B, in top horizontal well long oil pipe and short oil pipe, simultaneously continuously inject well head steam quality be the steam of 90%, steam injection rate 120t/d, 2 months steam injection time.Bottom producing well keeps flowing bottomhole pressure (FBHP) 3.5MPa to produce.
C, steam, carbon dioxide and thinner are injected oil reservoir by upper water horizontal well simultaneously, inject 30d continuously.Wherein, steam is injected continuously by upper water horizontal well long oil pipe, and well head steam quality is 90%, steam injection rate 120t/d; Thinner is injected by short oil pipe, and implantation quality concentration is 20%, and injection rate is at 0.5t/h; Carbon dioxide is injected by casing annulus, injection rate 180Nm
3/ h; Bottom producing well keeps flowing bottomhole pressure (FBHP) 3.5MPa to produce.
D, stopping carbon dioxide injection and thinner, continue to inject steam to top horizontal well, lower horizontal well continues to produce 60d, and working system remains unchanged.
E, repetition step C and D.
Claims (10)
1. improve the method for super-thick oil reservoir recovery efficiency, it is characterized in that, the method for this raising super-thick oil reservoir recovery efficiency comprises:
Step 1, carries out preheating by the horizontal well of two mouthfuls of parallel distributions;
Step 2, injects steam to top horizontal well, and lower horizontal well keeps original formation pressure to produce;
Step 3, injects oil reservoir by upper water horizontal well by steam, carbon dioxide and thinner simultaneously, and lower horizontal well keeps original formation pressure to produce; And
Step 4, stops carbon dioxide injection and thinner, continues to inject steam to top horizontal well, and lower horizontal well continues to produce.
2. the method for raising super-thick oil reservoir recovery efficiency according to claim 1, it is characterized in that, in step 1, in heavy crude reservoir oil reservoir, dispose about 2 mouthfuls just to parallel level distribution well, position is bottom oil reservoir, and two mouthfuls of wells keep certain distance, adopts steam injection cyclic preheat technology to carry out preheating.
3. the method for raising super-thick oil reservoir recovery efficiency according to claim 1, is characterized in that, in step 1, preheating time is 3-4 month.
4. the method for raising super-thick oil reservoir recovery efficiency according to claim 1, is characterized in that, in step 1, two mouthfuls of water horizontal wells all adopt double tube structure, wherein, the steam injection of long oil pipe, steam injection rate remains on 50-80t/d; Short oil pipe stable bottom hole pressure discharge opeing simultaneously, upper water horizontal well is a little more than lower horizontal well, and pressure reduction is 0.1MPa-0.2MPa.
5. the method for raising super-thick oil reservoir recovery efficiency according to claim 4, is characterized in that, in step 2, in top horizontal well long oil pipe and short oil pipe, inject well head steam quality is continuously the steam of 90% simultaneously, steam injection rate 100-150t/d.
6. the method for raising super-thick oil reservoir recovery efficiency according to claim 4, is characterized in that, in step 3, steam is injected continuously by upper water horizontal well long oil pipe, and well head steam quality is 90%, steam injection rate 80-120t/d; Thinner is injected by short oil pipe, and implantation quality concentration is 10-30%, and injection rate is at 0.4-0.8t/h; Carbon dioxide is injected by casing annulus, injection rate 120-180Nm
3/ h.
7. the method for raising super-thick oil reservoir recovery efficiency according to claim 1, is characterized in that, in step 2, the steam injection time is 1-3 month.
8. the method for raising super-thick oil reservoir recovery efficiency according to claim 1, is characterized in that, in step 3, steam, carbon dioxide and thinner is injected oil reservoir by upper water horizontal well simultaneously, injects 20-30d continuously.
9. the method for raising super-thick oil reservoir recovery efficiency according to claim 1, is characterized in that, in step 4, lower horizontal well continues to produce 30-60d, and working system remains unchanged.
10. the method for raising super-thick oil reservoir recovery efficiency according to claim 9, is characterized in that, the method for this raising super-thick oil reservoir recovery efficiency also comprises, and after step 4, repeats step 3 and step 4, to improve super-thick oil reservoir recovery efficiency.
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| CN107558974A (en) * | 2017-09-04 | 2018-01-09 | 中国石油化工股份有限公司华东油气分公司泰州采油厂 | A kind of horizontal wells in heavy oil reservoir precipitation yield-increasing technology |
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| CN115387767A (en) * | 2021-05-20 | 2022-11-25 | 中国石油化工股份有限公司 | Steam huff-puff effect-inducing superposition viscosity reducer flooding method for deep extra-heavy oil reservoir |
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| CN107664030A (en) * | 2016-07-29 | 2018-02-06 | 中国石油化工股份有限公司 | Super-heavy oil deposit horizontal well steam drives the method for improving recovery ratio |
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| CN110905460A (en) * | 2019-12-02 | 2020-03-24 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN110905460B (en) * | 2019-12-02 | 2021-08-20 | 中国石油化工股份有限公司 | Viscosity-reducing foaming exploitation method for common heavy oil reservoir |
| CN115387767A (en) * | 2021-05-20 | 2022-11-25 | 中国石油化工股份有限公司 | Steam huff-puff effect-inducing superposition viscosity reducer flooding method for deep extra-heavy oil reservoir |
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Application publication date: 20151014 |