CN102251763A - Composite profile control and oil displacement extraction method for thickened oil reservoir through water injection and exploitation - Google Patents
Composite profile control and oil displacement extraction method for thickened oil reservoir through water injection and exploitation Download PDFInfo
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Abstract
The invention relates to a composite profile control and oil displacement extraction method for a thickened oil reservoir through water injection and exploitation. The method provided by the invention comprises the following steps: preparing a polymer and water into a polymer solution with the concentration of 500-5000mg/L; preparing a cross-linking agent and water into a cross-linking agent solution with the concentration of 500-5000mg/L; mixing the polymer solution and the cross-linking agent solution according to the mass ratio of (1:1)-(10:1) to obtain a polymer gel solution; preparing a movable micro-gel and water into a movable micro-gel solution with the concentration of 1000-5000mg/L; respectively injecting the polymer gel solution and the movable micro-gel solution into a well to form an oil displacement segmentation plug, wherein the polymer is partial hydrolysis polyacrylamide; the cross-linking agent is an organic chromium cross-linking agent; and the movable micro-gel is a copolymer of acrylamide and N-N methylene bisacrylamide. The method provided by the invention can obviously improve the anisotropism in storage layers, among the layers and on planes, relieves the water injection and exploitation contradictions of the oil reservoir, solves the problems of tonguing and fingering and obviously enlarges the swept volume of a displacing solution, thereby greatly improving the recovery ratio of crude oil.
Description
Technical field
The present invention relates to the compound transfer drive oil production method of a kind of waterflooding extraction heavy crude reservoir, belong to oil recovery technique field, oil field.
Background technology
Characteristics such as the common heavy oil reservoir ubiquity layer of waterflooding extraction is interior, the strong non-homogeneity of interlayer, viscosity ratio of oil and water height, because the height infiltration circulation road that the long-term injecting water exploitation forms, cause injecting in a large number water poor efficiency, invalid circulation, in interlayer, the layer, horizontal contradiction is outstanding, fault block faces the severe situation of " three Senior Three difficulties ": moisture, the high recovery percent of reserves of height, high residue rate of oil production, newly-increased mining-employed reserves difficulty, remaining oil are described difficulty, the technology of taping the latent power is taken over difficulty.The conventional waterflooding effect is variation day by day, and it is bigger further to improve water drive development degree difficulty.
At this oil reservoir development field recognized problem, many researchers have proposed some solutions.People such as Du Yuhong (Du Yuhong, Wu Hangcai, Chen Hong, Ceng Qingqiao, the movable application of gel profile control technology in common heavy oil reservoir, Southwest Petrol University's journal, 2008,30 (3)) method that a kind of movable gel profile control technology is improved water drive exploitation common heavy oil reservoir development effectiveness has been proposed, this method adopts polymer and chromium cross-linking agent carboxylate to be mixed with movable gel rubber system, adopts skid-mounted type injection technology flow process to carry out the mining site construction.From laboratory experiment and field test result, this method has the advantage of aspects such as section adjustment, fluid diversion.
But there is following problem at least in prior art: the one, and the movable gel viscosity height that injects, mobile poor, be difficult to advance into the reservoir depths and carry out that layer is interior, the plane adjustment, treatment radius is confined to inject near the well, and raising recovery ratio amplitude is limited.The 2nd, because the high prop-carrying capacity of injecting of movable gel viscosity is strong, make that the heavy crude reservoir of the reservoir loose cementation situation of shaking out is more serious, appreciable impact oil well liquid-producing ability can cause oil well to be forced to close when serious.
Summary of the invention
For solving the problems of the technologies described above, the object of the present invention is to provide a kind of new oil production method, by adopting compound transfer drive, significantly improve the contradiction of the high water-cut stage waterflooding extraction of oil reservoir, solve tonguing, fingering phenomenon, improve the recovery ratio of waterflooding extraction heavy crude reservoir.
For achieving the above object, the invention provides the compound transfer drive oil production method of a kind of waterflooding extraction heavy crude reservoir, it may further comprise the steps:
Polymer and water are mixed with the polymer solution that concentration is 500-5000mg/L;
Crosslinking agent and water are mixed with the cross-linking agent solution that concentration is 500-5000mg/L;
With polymer solution and cross-linking agent solution by 1: 1-10: 1 mass ratio mixes and obtains polymer gel solution;
Movable microgel and water are mixed with the movable microgel solution that concentration is 1000-5000mg/L;
Polymer gel solution and movable microgel solution are injected well formation displacement of reservoir oil slug respectively;
Wherein, the polymer that is adopted is partially hydrolyzed polyacrylamide (PHPA) (HPAM), and the crosslinking agent that is adopted is Organic Chromium crosslinking agent YG107, and the movable microgel that is adopted is acrylamide and N-N methylene-bisacrylamide copolymer.
In said method provided by the invention, preferably, the degree of hydrolysis of partially hydrolyzed polyacrylamide (PHPA) is 30%-40%.
In said method provided by the invention, preferably, the injection rate of polymer gel solution is 0.01-0.05 a times of oil reservoir voids volume.
In said method provided by the invention, preferably, the injection rate of movable microgel solution is 0.1-0.5 a times of oil reservoir voids volume.
The unit of oil reservoir voids volume, polymer gel solution injection rate and movable microgel solution injection rate is m
3
In said method provided by the invention, preferably, the diameter of the movable microgel that is adopted is 1-5 μ m.
According to concrete technical scheme of the present invention, preferably, said method can comprise following concrete steps:
Polymer and water are mixed with the polymer solution that concentration is 3000mg/L;
Crosslinking agent and water are mixed with the cross-linking agent solution that concentration is 1500mg/L;
Polymer solution and cross-linking agent solution mixed by 2: 1 mass ratio obtain polymer gel solution;
Movable microgel and water are mixed with the movable microgel solution that concentration is 2000mg/L;
Polymer gel solution and movable microgel solution are injected well formation displacement of reservoir oil slug respectively;
Wherein, the injection rate of polymer gel solution is 0.01 times of oil reservoir voids volume, and the injection rate of movable microgel solution is 0.19 times of oil reservoir voids volume.
In said method provided by the present invention, polymer gel solution and movable microgel solution can adopt the mode of periodically alternately injecting to inject, and the injection cycle may be controlled to 60-120 days, and the concrete cycle can decide on the pressure condition of injecting well.
It is that 0-100 ℃ of (being preferably 0-80 ℃), formation water salinity are that 0-10000mg/L (being preferably 0-8000mg/L), 70 ℃ of underground viscosity of crude oil are that 0-150mP.s (being preferably 0-100mP.s), permeability are 500 * 10 that said method provided by the present invention is suitable for reservoir temperature
-3-3000 * 10
-3μ m
2Oil reservoir.
The transfer drive system that adopts in the compound transfer drive oil production method of waterflooding extraction heavy crude reservoir provided by the invention is the compound system of a kind of cross-linking polymer system and functional form acrylamide copolymer, wherein, the main component of cross-linking polymer system is partially hydrolyzed polyacrylamide (PHPA) HPAM and Organic Chromium crosslinking agent, the Main Ingredients and Appearance of functional form acrylamide copolymer is acrylamide and N-N methylene-bisacrylamide, is the acrylamide and the N-N methylene-bisacrylamide copolymer of a series of grafting, block.Cross-linking polymer system mainly plays the effect of interlayer profile control, and functional form acrylamide copolymer-movable microgel itself both can be used as profile control agent and also can be used as oil displacement agent.The movable microgel that the present invention adopts is used for profile control and does the time spent, movable microgel is not that macropore is blocked, but temporarily hinder the migration of fluid in the macropore, make fluid in interlayer, layer, flow in the lower low-permeability layer of osmotic resistance, thereby enlarge swept volume.Movable microgel is piled up macropore plugging by building bridge at interstitial space makes follow-up water stream, when the shutoff build-up of pressure raises, when pressure reduction is elevated to a certain degree, elastic deformation can take place again in movable microgel, pass through pore constriction, continuation is migrated to the reservoir deep, the place produces temporary transient shutoff at the big venturi of the next one, therefore movable microgel is a migration in reservoir pore space, shutoff, distortion is passed through, migration again, the so reciprocal constantly process of shutoff again, thereby on three dimensions, constantly the fluid in the reservoir is flowed to adjustment, effectively enlarge swept volume, improve recovery percent of reserves.
The compound transfer drive oil production method of waterflooding extraction heavy crude reservoir provided by the present invention is based on the strong characteristics of waterflooding extraction heavy crude reservoir non-homogeneity, by injecting compound transfer drive system, give full play to the profile control mechanism of action of polymer gel in the compound system and the deep transfer drive mechanism of action of movable microgel, can significantly improve in the reservoir layer, interlayer, plane heterogeneity, alleviate reservoir waterflooding contradiction, solve tonguing, the fingering problem, significantly enlarge the swept volume of displacing fluid, thereby increase substantially oil recovery factor, daily flow can increase 30%-50% after indoor core experiment and field test showed the compound transfer drive oil production method of enforcement waterflooding extraction heavy crude reservoir provided by the invention.
The compound transfer drive oil production method of waterflooding extraction heavy crude reservoir provided by the invention has following outstanding feature:
1,, can obviously increase the swept volume and the oil displacement efficiency of displacing fluid in compound transfer drive system injection period.
(1) polymer gel in the compound transfer drive system has the mobility ratio that higher viscosity can significantly be improved profit on the one hand, has stronger shut-off capacity on the other hand, the high permeability formation shutoff can be improved the reservoir interlayer heterogeneity.
(2) the movable microgel in the compound transfer drive system is the elasticity orbicule, but in the temporarily blocking layer, the high pore throat that oozes in the passage in plane, make displacing fluid turn in hypotonic position, the oil reservoir vertical profile becomes more even, the all directions displacement velocity is bordering on unanimity on the plane, thereby further enlarges swept volume.After displacement pressure surpassed movable microgel breakthrough pressure, movable microgel began to move to the shutoff again of next pore throat place, and this breakthrough-shutoff process has further increased oil displacement efficiency.
2, the follow-up water drive stage after compound transfer drive system is injected because compound transfer drive system has significantly reduced water phase permeability, has reduced the crude oil flow resistance, makes further to have enlarged water drive swept volume and oil displacement efficiency in the follow-up water drive process.
After artificial core experiment structure showed injection of polymer gel and the movable compound transfer drive system of microgel, recovery ratio can improve more than 10%, and overall recovery factor reaches more than 80%.
The present invention can be applied in waterflooding extraction heavy crude reservoir and waterflooding extraction ligh-oil reservoir exploitation middle and later periods, further improve oil recovery factor for the oil field a kind of new effective ways are provided, be applicable to that reservoir temperature is not higher than 100 ℃, formation water salinity is no more than 10000mg/L, the underground viscosity of crude oil is lower than 150mP.s, and permeability is 500 * 10
-3-3000 * 10
-3μ m
2Oil reservoir.
Description of drawings
Fig. 1 is the dynamic oil displacement efficiency curve of the artificial core of non-average that provides of embodiment 1.
The specific embodiment
Understand for technical characterictic of the present invention, purpose and beneficial effect being had more clearly, technical scheme of the present invention is carried out following detailed description, but but can not be interpreted as qualification practical range of the present invention referring now to Figure of description.
The artificial core oil displacement experiment of the embodiment non-average of 1 compound transfer drive system
Experiment condition:
Artificial non-average core model in parallel: permeability is respectively 2000md, 380md.
Experiment is with oily: taking from the degassing dewatered oil in 1 in sea, Liaohe Oil Field, is 75.0mPa.s 70 ℃ of following viscosity.
Experimental water: take from the Simulated Water of sea, Liaohe Oil Field 4 station dosings with sewage, salinity is 2286.5mg/L.
Compound profile control agent: partially hydrolyzed polyacrylamide (PHPA) (Beijing Hengju Chemical Group Co., Ltd's product) solution of concentration 3000mg/L and the mixing of the Organic Chromium crosslinking agent YG107 of concentration 1500mg/L (Shandong Province Micron Technology Co., Ltd of Dongying dan Daewoo product) solution are re-dubbed polymer gel solution, and the mass ratio of the two is 1: 1;
Concentration is the movable microgel of the micron order of 2000mg/L (product that stone big ten thousand good energy and environment science and technology limited Company in Beijing are produced) solution, the diameter d of the movable microgel of micron order=1-5 μ m.
Experimental temperature: 70 ℃.
Experimental procedure:
(1) the core model was found time 3-4 hour, make core saturation simulation formation water (experimental water) then, measure the voids volume in the core;
(2) core with the saturation simulation formation water is put in the insulating box, and 70 ℃ of following constant temperature were placed 15 hours;
(3) in model, be 633 * 10 70 ℃ of permeabilities that down record core with simulated formation water
-3μ m
2
(4) saturated oils: model is vertically put well, carried out oily expelling water from top to bottom and handle, till core exports not water breakthrough, calculate initial oil saturation and irreducible water saturation;
(5) water drive oil: the displacement velocity with 1.5mL/min carries out the water drive oil processing, and the moisture content up to the core exit reaches at 95% o'clock finishes water drive oil, calculates waterflood recovery efficiency factor;
(6) annotate compound transfer drive system:, inject the movable microgel of micron order of 0.19 times of voids volume then with the polymer gel solution of 0.01 times of voids volume of speed injection identical with water drive oil;
(7) carry out the later stage water drive with the displacement velocity identical with water drive oil and handle, the moisture content up to the core exit reaches end in 95% o'clock, calculates transfer drive recovery ratio and ultimate recovery.
Experimental result:
Fig. 1 is the dynamic oil displacement efficiency curve of the artificial core of non-average, is followed successively by moisture content, recovery ratio and barometric gradient from top to bottom.According to above-mentioned experimental result and Fig. 1 as can be seen: inject compound profile control agent, can increase recovery ratio 15.16% on the basis of water drive, overall recovery factor 70.41% during by water drive brings up to 85.57%.It can also be seen that from Fig. 1, after injecting compound profile control agent, pressure curve raises and has wave phenomenon, show that compound profile control agent has played the effect of temporary transient shutoff high permeability formation, after pressure is higher than breakthrough pressure, compound profile control agent is broken through pore throat and is migrated to next pore throat place, place and produce shutoff, and the pressure after follow-up water drive is handled decreases but still pressure when being higher than original water drive and handling.
Embodiment 2
Present embodiment is the embodiment of compound profile control agent in actual production, and it may further comprise the steps:
(1) polymer is mixed with water to obtain concentration be the polymer solution of 2500mg/L and pump in the storage tank, then crosslinking agent is mixed with water that to obtain concentration be the cross-linking agent solution of 1250mg/L and pump in the above-mentioned storage tank, the mass ratio of the two is 2: 1, fully mix and obtain polymer gel solution, stand-by;
(2) the movable microgel of micron order is mixed with water obtain the movable microgel solution that concentration is 2000mg/L, pump in another storage tank, after fully stirring, stand-by;
(3) utilize pump for well that polymer gel solution is pumped into water injection well, injection rate is 0.01 times of oil reservoir voids volume;
(4) by pump for well movable microgel solution is pumped into water injection well, injection rate is 0.19 times of oil reservoir voids volume.
Wherein, the polymer that step (1) is adopted is that (Beijing Hengju Chemical Group Co., Ltd produces partially hydrolyzed polyacrylamide (PHPA) HPAM, degree of hydrolysis is 30-40%), crosslinking agent is Organic Chromium crosslinking agent YG107 (production of Shandong Province Micron Technology Co., Ltd of Dongying dan Daewoo), and movable microgel is acrylamide and N-N methylene-bisacrylamide copolymer (stone big ten thousand good energy and environment science and technology limited Company in Beijing are produced).
In order to reach the better implement effect, polymer gel solution and movable microgel solution can periodically hocket in the present embodiment, and the injection cycle is 60 days, and promptly above-mentioned steps (3) and step (4) were implemented once every 60 days.
Embodiment 3
Present embodiment provides a method that improves the waterflooding reservoir recovery ratio, and it may further comprise the steps:
(1) when oil reservoir moisture percentage is above above 80%, polymer solution and the concentration that at first with concentration is 3000mg/L is that the cross-linking agent solution of 1500mg/L mixes the polymer gel solution that (mass ratio of the two is 1: 1) obtain and pumps into water injection well by pump for well, wherein, the injection rate of polymer gel solution is 0.01 times of voids volume;
(2) then the movable microgel solution of micron order is pumped into water injection well by pump for well, wherein, the diameter d of the movable microgel of micron order is 1-5 μ m, and the concentration of the movable microgel solution of micron order is 2000mg/L, and the injection rate of the movable microgel solution of micron order is 0.19 times of oil reservoir voids volume.
The polymer that present embodiment adopted is that (sea, Liaohe Oil Field billows chemical industry Co., Ltd produces partially hydrolyzed polyacrylamide (PHPA) HPAM, degree of hydrolysis is 30-40%), crosslinking agent is Organic Chromium crosslinking agent YG107 (production of Shandong Province Micron Technology Co., Ltd of Dongying dan Daewoo), and movable microgel is acrylamide and N-N methylene-bisacrylamide copolymer (stone big ten thousand good energy and environment science and technology limited Company in Beijing are produced).
Embodiment 4
With sea, Liaohe Oil Field 4-17 well group is example, and this well group oil in place recovery percent of reserves is 36.3%, and comprehensive water cut is 87.9%, day produce oil 20.4t.
The method of the raising waterflooding reservoir recovery ratio that provides according to embodiment 3 is injected after the compound profile control agent, the water cut decreases to 74% of well group, and a day produce oil is increased to 34t, has obtained obvious effects.
This shows that the method for raising waterflooding reservoir recovery ratio provided by the present invention can be applied in waterflooding extraction heavy crude reservoir and waterflooding extraction ligh-oil reservoir exploitation middle and later periods, further improving oil recovery factor for the oil field provides a kind of new effective ways.
Above-described specific embodiment; purpose of the present invention, technical scheme and beneficial effect are further described; institute is understood that; the above only is specific embodiments of the invention; and be not intended to limit the scope of the invention; within the spirit and principles in the present invention all, any modification of being made, be equal to replacement, improvement etc., all should be included within protection scope of the present invention.
Claims (9)
1. compound transfer drive oil production method of waterflooding extraction heavy crude reservoir, it may further comprise the steps:
Polymer and water are mixed with the polymer solution that concentration is 500-5000mg/L;
Crosslinking agent and water are mixed with the cross-linking agent solution that concentration is 500-5000mg/L;
With polymer solution and cross-linking agent solution by 1: 1-10: 1 mass ratio mixes and obtains polymer gel solution;
Movable microgel and water are mixed with the movable microgel solution that concentration is 1000-5000mg/L;
Polymer gel solution and movable microgel solution are injected well formation displacement of reservoir oil slug respectively;
Wherein, described polymer is a partially hydrolyzed polyacrylamide (PHPA), and described crosslinking agent is the Organic Chromium crosslinking agent, and described movable microgel is acrylamide and N-N methylene-bisacrylamide copolymer.
2. method according to claim 1, wherein, the degree of hydrolysis of described partially hydrolyzed polyacrylamide (PHPA) is 30%-40%.
3. method according to claim 1, wherein, the injection rate of described polymer gel solution is 0.01-0.05 a times of oil reservoir voids volume.
4. method according to claim 1, wherein, the injection rate of described movable microgel solution is 0.1-0.5 a times of oil reservoir voids volume.
5. method according to claim 1, the diameter of described movable microgel are 1-5 μ m.
6. method according to claim 1, it may further comprise the steps:
Polymer and water are mixed with the polymer solution that concentration is 3000mg/L;
Crosslinking agent and water are mixed with the cross-linking agent solution that concentration is 1500mg/L;
With polymer solution and cross-linking agent solution by 1: 1-10: 1 mass ratio mixes and obtains polymer gel solution;
Movable microgel and water are mixed with the movable microgel solution that concentration is 2000mg/L;
Polymer gel solution and movable microgel solution are injected well formation displacement of reservoir oil slug respectively;
Wherein, the injection rate of described polymer gel solution is 0.01 times of oil reservoir voids volume, and the injection rate of described movable microgel solution is 0.19 times of oil reservoir voids volume.
7. according to claim 1 or 6 described methods, wherein, described polymer gel solution and movable microgel solution are periodically alternately to inject.
8. method according to claim 7, wherein, the described cycle is 60-120 days.
9. according to each described method of claim 1-8, wherein, described heavy crude reservoir is that reservoir temperature is that 0-100 ℃, formation water salinity are that 0-10000mg/L, 70 ℃ of underground viscosity of crude oil are that 0-150mP.s, permeability are 500 * 10
-3-3000 * 10
-3μ m
2Oil reservoir.
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| CN103113873A (en) * | 2013-03-05 | 2013-05-22 | 中国石油大学(华东) | Modifying and flooding agent for reutilization of residual polymers in formation and application thereof |
| CN104329082A (en) * | 2014-10-24 | 2015-02-04 | 中国海洋石油总公司 | Method for determining high-permeability thick-oil oil reservoir polymer flooding early stage polymer injection transfer occasion |
| CN104727789A (en) * | 2013-12-23 | 2015-06-24 | 中国石油化工股份有限公司 | Dynamic description method of medium-high-permeability sandstone reservoir water flooding sweep efficiency and water flooding pore volumes |
| CN104929597A (en) * | 2015-06-10 | 2015-09-23 | 中国石油天然气股份有限公司 | Horizontal well chemical flooding mining method |
| CN105649587A (en) * | 2016-02-29 | 2016-06-08 | 烟台智本知识产权运营管理有限公司 | Method for conducting deep profile control over medium-high permeability oil reservoir |
| CN106014359A (en) * | 2016-06-08 | 2016-10-12 | 西南石油大学 | Method for judging earliest injection transfer opportunity of early-stage polymer injection of offshore oil deposit |
| CN109933899A (en) * | 2019-03-13 | 2019-06-25 | 中国石油大学(华东) | A kind of water drive old filed cyclic waterflooding development cycle calculates plate and determines method |
| CN110242265A (en) * | 2019-06-14 | 2019-09-17 | 西南石油大学 | Original position receive-microballoon improve oil recovery factor filed application method |
| CN111334277A (en) * | 2020-03-09 | 2020-06-26 | 陕西中诺油气科技有限公司 | Microorganism composite movable gel for oil displacement of oil field and preparation method and application thereof |
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| CN102619492A (en) * | 2012-02-23 | 2012-08-01 | 中国石油天然气股份有限公司 | Polymer flooding alternating injection method of heterogeneous oil reservoir |
| CN103087699A (en) * | 2012-12-27 | 2013-05-08 | 中国石油化工股份有限公司 | Sand-carrying profile control agent composition of fracture-cave type oil deposit and profile control method of profile control agent |
| CN103087699B (en) * | 2012-12-27 | 2015-05-20 | 中国石油化工股份有限公司 | Sand-carrying profile control agent composition of fracture-cave type oil deposit and profile control method of profile control agent |
| CN103113873A (en) * | 2013-03-05 | 2013-05-22 | 中国石油大学(华东) | Modifying and flooding agent for reutilization of residual polymers in formation and application thereof |
| CN103113873B (en) * | 2013-03-05 | 2014-06-18 | 中国石油大学(华东) | Modifying and flooding agent for reutilization of residual polymers in formation and application thereof |
| CN104727789B (en) * | 2013-12-23 | 2017-05-10 | 中国石油化工股份有限公司 | Dynamic description method of medium-high-permeability sandstone reservoir water flooding sweep efficiency and water flooding pore volumes |
| CN104727789A (en) * | 2013-12-23 | 2015-06-24 | 中国石油化工股份有限公司 | Dynamic description method of medium-high-permeability sandstone reservoir water flooding sweep efficiency and water flooding pore volumes |
| CN104329082B (en) * | 2014-10-24 | 2017-02-15 | 中国海洋石油总公司 | Method for determining high-permeability thick-oil oil reservoir polymer flooding early stage polymer injection transfer occasion |
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| CN104929597A (en) * | 2015-06-10 | 2015-09-23 | 中国石油天然气股份有限公司 | Horizontal well chemical flooding mining method |
| CN105649587A (en) * | 2016-02-29 | 2016-06-08 | 烟台智本知识产权运营管理有限公司 | Method for conducting deep profile control over medium-high permeability oil reservoir |
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