CN102562012B - Method for improving recovery ratio of normal heavy oil reservoirs in water-flooding development - Google Patents
Method for improving recovery ratio of normal heavy oil reservoirs in water-flooding development Download PDFInfo
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- CN102562012B CN102562012B CN201010622259.1A CN201010622259A CN102562012B CN 102562012 B CN102562012 B CN 102562012B CN 201010622259 A CN201010622259 A CN 201010622259A CN 102562012 B CN102562012 B CN 102562012B
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Abstract
The invention discloses a method for improving the recovery ratio of normal heavy oil reservoirs in water-flooding development, comprising the steps of (1) preparing microgel and water to be 1000-3000mg/l of solution; (2), preparing surfactants and water to be 2000-3000mg/l of solution; and (3), filling a microgel solution slug and a surfactant solution slug from a water well, wherein the microgel is copolymer of acrylic amide and methylene diacrylamide; the surfactant is alkylbenzene sulfonate surfactant. In the invention, based on the characteristic of strong anisotropy of the water-flooding developed reservoirs, the method fully uses a movable microgel profile control action mechanism and a surfactant oil-displacing action mechanism in a composite system through a filled composite microgel profile control system, so that the method can improve the anisotropy in reservoir stratums and among reservoir stratums, solve a fingering condition, increase water-displacing waves and volumes and improve the displacement efficiency, thereby drastically improving the oil recovery; indoor core tests show that the total recovery ratio is up to 80-90%.
Description
Technical field
The invention belongs to field of oil field oil extraction, particularly a kind of method improving recovery ratio of normal heavy oil reservoirs in water-flooding development.
Background technology
The common heavy oil reservoir of waterflooding development, due in ubiquity layer, the strong non-homogeneity of interlayer, viscosity ratio of oil and water high feature, make reservoir waterflooding there is serious tonguing, fingering phenomenon.When after late period of oil field, tonguing, fingering phenomenon are more obvious, have a strong impact on the raising of crude oil recovery percent of reserves.
Around the development effectiveness how improving such oil reservoir, increase this problem of recoverable reserves, many experts are making great efforts in discussion always for many years.The people such as Du Yuhong (Du Yuhong, Wu Hangcai, Chen Hong, Zeng Qingqiao, the application of flowing gel profile control technique in common heavy oil reservoir, Southwest Petrol University's journal, 2008,30 (3)) once proposed the method for flowing gel profile control technique improving ecology exploitation common heavy oil reservoir development effectiveness in 2008, this technology adopts polymer to add chromium cross-linking agent carboxylate and is mixed with weak gel system, adopts skid-mounted type injection technology flow process to carry out mining site construction.Experiment and field test result are seen indoor, and the method has section adjustment, fluid diversion and improves the advantage of the aspects such as oil-displacement capacity.
Realizing in process of the present invention, inventor finds that prior art at least exists following problem: field test shortcoming: one is that flowing gel profile control technique adopts polymer and crosslinking agent to inject underground in certain sequence, make the two underground crosslinked thus carry out shutoff to high aquifer formation, because system needs underground crosslinked, therefore plastic reliability, poor controllability, mining site body ties up to underground not plastic phenomenon, greatly have impact on and improves recovery ratio effect; Two is that the weak gel system viscosity injected is too high, and be difficult to advance into the object that reservoir depths reaches reservoir deep rock tunneling, treatment radius is too small, improves recovery ratio limited extent.
Summary of the invention
The object of the embodiment of the present invention is the defect for above-mentioned prior art, provides a kind of method, and the method can be improved in reservoir layer, interlayer heterogeneity, solves tonguing, fingering phenomenon, thus improves recovery ratio of normal heavy oil reservoirs in water-flooding development.
The technical scheme that the present invention takes to achieve these goals is: a kind of method improving recovery ratio of normal heavy oil reservoirs in water-flooding development, comprises the following steps:
(1) microgel and water are configured to concentration 1000-3000mg/l solution;
(2) surfactant and water are configured to concentration 2000-3000mg/l solution;
(3) microgel solution slug and surfactant solution slug is injected from well;
Described microgel is acrylamide and methylene diacrylamide copolymer;
Described surfactant is alkyl benzene sulfonate surfactant.
Described microgel solution slug injection rate is 0.18 times of oil reservoir voids volume.
Described surfactant slug injection rate is 0.02 times of oil reservoir voids volume.
The preferred technical scheme of the present invention: the method improving recovery ratio of normal heavy oil reservoirs in water-flooding development, comprises the following steps:
(1) microgel and water are configured to concentration 1000-3000mg/l solution;
(2) surfactant and water are configured to concentration 2000-3000mg/l solution;
(3) from well, following slug is injected successively: inject 0.08 times of movable microgel of oil reservoir voids volume submillimeter level, the movable microgel diameter d of described submillimeter level is 10-100 μm, concentration 1000-3000mg/l; 0.1 times of movable microgel of oil reservoir voids volume micron order, the movable microgel diameter d of described micron order is 1-5 μm, concentration 1000-3000mg/l; 0.02 times of oil reservoir voids volume surfactant, described surfactant concentration is 2000-3000mg/l.
The preferred technical scheme of the present invention: the method improving recovery ratio of normal heavy oil reservoirs in water-flooding development, comprises the following steps:
(1) first movable for submillimeter level microgel is pumped into waterflood-transmission line, be configured to the preposition shutoff slug of concentration 1000-3000mg/l, injection rate is 0.08 times of voids volume.
(2) then according to 4: 1 ratios, movable for micron order microgel and surfactant mixing are pumped into waterflood-transmission line, be configured to the transfer drive principal piece plug of concentration 2000mg/l, injection rate is 0.1 times of voids volume.
(3) finally movable for submillimeter level microgel is pumped into waterflood-transmission line, be configured to the rearmounted sealing slug of concentration 1000mg/l, injection rate is 0.02 times of voids volume.
Described microgel slug and surfactant slug and sequent water flooding slug are periodically alter least-squares, and the injection cycle is 30-100 days.
The beneficial effect that the technical scheme that the embodiment of the present invention provides is brought is:
The present invention is based on the feature that waterflooding development Reservoir Heterogeneity is strong, by injecting composite microgel transfer drive system, give full play to the movable microgel profile control mechanism of action and the surfactant flooding mechanism of action in compound system, can improve in reservoir layer, interlayer heterogeneity, solve tonguing, fingering phenomenon, while increase water drive swept volume, turn improve displacement efficiency, thus increased substantially oil recovery factor, laboratory core experiment shows that overall recovery factor can up to 80-90%.
The present invention has following outstanding feature:
1. composite microgel transfer drive system injection period, obviously can increase swept volume and the oil displacement efficiency of displacing fluid.
(1) microgel in composite microgel transfer drive system is elastomeric spherical body, height can be blocked up temporarily and ooze passage, hypotonic position during displacing fluid is turned to, oil reservoir vertical profile become evenly, in plane, all directions displacement velocity is bordering on unanimously, thus expands swept volume.
(2) alkyl benzene sulfonate surfactant in composite microgel transfer drive system significantly can reduce oil water interfacial tension, reduces crude oil flow resistance, thus improves oil displacement efficiency.
2. in the sequent water flooding stage after the injection of composite microgel transfer drive system, because compound displacement system reduces water phase permeability, reduces crude oil flow resistance, make to expand water drive swept volume and oil displacement efficiency further in sequent water flooding process.
After the artificial core experiment of the embodiment of the present invention shows to inject microgel compound displacement system, recovery ratio can improve 10-40%, and overall recovery factor reaches 80-90%.
Certain Cut of Oilfield 96.8%, recovery percent of reserves 43.2%, after injecting compound displacement system, pilot wellgroup comprehensive water cut drops to 90%, day produce oil be increased to 8.5t/d by 2.9t/d, achieve better effects.
The present invention can in waterflooding development common heavy oil reservoir and ligh-oil reservoir development late stage, improve oil recovery factor further for oil field and a kind of new effective method is provided, be applicable to reservoir temperature not higher than 120 DEG C, preferred 0-120 DEG C, formation water salinity is no more than 180000mg/l, preferred 0-180000mg/l, and crude oil underground viscosity is lower than 150mP.s, preferred 0-150mP.s, permeability 200 × 10
-3μm
2-3000 × 10
-3μm
2oil reservoir.
Accompanying drawing explanation
Fig. 1 is the dynamic displacement of reservoir oil curve of filling sandpipe artificial cores according to the non-average provided in the embodiment of the present invention 1;
Fig. 2 is the dynamic displacement of reservoir oil curve of filling sandpipe artificial cores according to the non-average provided in the embodiment of the present invention 2.
Detailed description of the invention
For making the object, technical solutions and advantages of the present invention clearly, below in conjunction with accompanying drawing, embodiment of the present invention is described further in detail.
Embodiment 1: the artificial fill out sand tube core oil-displacement test of the non-average of composite microgel transfer drive system
Experiment condition:
The artificial fill out sand tube parallel core of non-average: permeability is respectively 3370md, 480md.
Experiment oil: the degassed dewatered oil taking from 1 piece, sea, Liaohe Oil Field, its viscosity is 75.0mPa s at 70 DEG C.
Experimental water: the Simulated Water taking from sea, Liaohe Oil Field 4 station dosing sewage, salinity is 2286.5mg/L
The movable microgel of compound displacement agent: 1000mg/l (product that the good energy and environment science and technology limited Company of Beijing stone large ten thousand is produced), 3000mg/l neopelex surfactant (U.S. SCI company ORS series of products) mix compound system.
Experimental temperature: 70 DEG C
Experimental procedure:
(1) physical model to be found time 4-5 hour, then saturation simulation formation water, measure voids volume;
(2) rock core of saturated brine is put in insulating box, constant temperature 16 hours at 70 DEG C;
(3) permeability Kw is surveyed with simulated formation water at physical model 70 DEG C;
(4) saturated oils: physical model is vertically put well, from top to bottom oily expelling water, rock core exports not till water breakthrough, calculates initial oil saturation and irreducible water saturation;
(5) water drive oil: terminate water drive oil when reaching 98% with the displacement velocity water drive oil of 1.5ml/min to rock core outlet is moisture, calculate waterflood recovery efficiency factor;
(6) compound displacement system is noted: inject the 0.08 times of movable microgel of voids volume submillimeter level (microgel diameter d=10-100 μm with the speed identical with water drive oil, concentration 1000mg/l), 0.1 times of movable microgel of voids volume micron order (microgel diameter d=1-5 μm, concentration 1000mg/l), 0.02 times of voids volume surfactant (concentration 3000mg/l).
(7) terminate when reaching 98% with the displacement velocity later stage water drive identical with water drive oil to rock core outlet is moisture, calculate transfer drive recovery ratio and ultimate recovery.
Experimental result:
See Fig. 1, experimental result shows: can increase recovery ratio 30.05% on water drive basis after injecting compound displacement system, overall recovery factor brings up to 83.87% by 53.82% during water drive.
Embodiment 2: the artificial fill out sand tube core oil-displacement test of the non-average of composite microgel transfer drive system
Experiment condition:
The artificial fill out sand tube parallel core of non-average: permeability is respectively 2810md, 510md.
Experiment oil: the degassed dewatered oil taking from 1 piece, sea, Liaohe Oil Field, its viscosity is 75.0mPa s at 70 DEG C.
Experimental water: the Simulated Water taking from sea, Liaohe Oil Field 4 station dosing sewage, salinity is 2286.5mg/L
The movable microgel of compound displacement agent: 1000mg/l (product that the good energy and environment science and technology limited Company of Beijing stone large ten thousand is produced), 3000mg/l DBSA ammonium surfactant (U.S. SCI company ORS series of products) mix compound system.
Experimental temperature: 70 DEG C
Experimental procedure:
(1) physical model to be found time 4-5 hour, then saturation simulation formation water, measure voids volume;
(2) rock core of saturated brine is put in insulating box, constant temperature 16 hours at 70 DEG C;
(3) permeability Kw is surveyed with simulated formation water at physical model 70 DEG C;
(4) saturated oils: physical model is vertically put well, from top to bottom oily expelling water, rock core exports not till water breakthrough, calculates initial oil saturation and irreducible water saturation;
(5) water drive oil: terminate water drive oil when reaching 98% with the displacement velocity water drive oil of 1.5ml/min to rock core outlet is moisture, calculate waterflood recovery efficiency factor;
(6) compound displacement system is noted: inject the 0.08 times of movable microgel of voids volume submillimeter level (microgel diameter d=10-100 μm with the speed identical with water drive oil, concentration 3000mg/l), 0.1 times of movable microgel of voids volume micron order (microgel diameter d=1-5 μm, concentration 3000mg/l), 0.02 times of voids volume surfactant (concentration 3000mg/l).
(7) terminate when reaching 98% with the displacement velocity later stage water drive identical with water drive oil to rock core outlet is moisture, calculate transfer drive recovery ratio and ultimate recovery.
Experimental result:
See Fig. 2, experimental result shows: after in compound displacement system, the concentration of microgel is increased to 3000mg/l from 1000mg/l, recovery ratio increase rate slightly increases.On water drive basis, increase recovery ratio 39.35% after injecting compound displacement system, overall recovery factor brings up to 90.92% by 51.57% during water drive.It can also be seen that from experimental result picture, after injecting compound displacement system, pressure curve raises and there is wave phenomenon, show that compound displacement system serves the effect of temporary transient shutoff high permeability formation, after pressure is higher than breakthrough pressure, compound displacement system breakthrough pore throat migrates to next pore throat place of place and produces shutoff.After sequent water flooding, pressure decreases but still higher than pressure during original water drive.
Embodiment 3: composite microgel transfer drive system mining site is implemented
(1) first movable for submillimeter level microgel is pumped into waterflood-transmission line by pump for well, be configured to the preposition shutoff slug of concentration 1000mg/l, injection rate is 0.08 times of oil reservoir voids volume.
(2), after then movable for micron order microgel and surfactant being mixed according to 4: 1 ratios, pump into waterflood-transmission line by pump for well, be configured to the transfer drive principal piece plug of concentration 2000mg/l, injection rate is 0.1 times of oil reservoir voids volume.
(3) finally movable for submillimeter level microgel is pumped into waterflood-transmission line by pump for well, be configured to the rearmounted sealing slug of concentration 1000mg/l, injection rate is 0.02 times of oil reservoir voids volume.
Microgel in the present embodiment is acrylamide and methylene diacrylamide copolymer, i.e. movable microgel; Surfactant is neopelex.
In order to reach better recovery ratio, the microgel slug of above-mentioned steps of the present invention and surfactant slug and sequent water flooding slug are periodically alter least-squares, and the injection cycle is 30 days, and namely above-mentioned steps needs to implement once every 30 days.
Embodiment 4: the method improving recovery ratio of normal heavy oil reservoirs in water-flooding development
(1) when water drive reaches moisture content more than 90%, first movable for submillimeter level microgel is pumped into waterflood-transmission line by pump for well, movable microgel diameter d is 10-100 μm, is configured to the preposition shutoff slug of concentration 2000mg/l, and injection rate is 0.08 times of voids volume.
(2) more movable for micron order microgel is pumped into waterflood-transmission line by pump for well, the movable microgel diameter d of micron order is 1-5 μm, is configured to the transfer drive principal piece plug of concentration 1000mg/l, and injection rate is 0.1 times of oil reservoir voids volume.
(3) finally surfactant is pumped into waterflood-transmission line by pump for well, be configured to the rearmounted sealing slug of concentration 3000mg/l, injection rate is 0.02 times of oil reservoir voids volume.
Microgel in the present embodiment is acrylamide and methylene diacrylamide copolymer, i.e. movable microgel; Surfactant is DBSA ammonium.
In order to reach better recovery ratio, the microgel slug of above-mentioned steps of the present invention and surfactant slug and sequent water flooding slug are periodically alter least-squares, and the injection cycle is 100 days, and namely above-mentioned steps needs to implement once every 100 days.
The transfer drive system that the present invention adopts is a kind of functional form acrylamide copolymer-movable microgel and alkyl benzene sulfonate surfactant compound system.Wherein the Main Ingredients and Appearance of functional form acrylamide copolymer is acrylamide and methylene diacrylamide, and movable microgel is a series of grafting, the acrylamide of block and methylene diacrylamide copolymer.Movable microgel itself both also can be used as oil displacement agent as profile control agent.When the movable microgel that the present invention adopts is used for profile control effect, microgel is not blocked by macropore, but temporarily hinders the migration of fluid in macropore, and fluid is flow in the lower low-permeability layer of osmotic resistance in interlayer, layer, thus expands swept volume.Microgel is piled up macropore plugging by building bridge at interstitial space and follow-up water is streamed, when shutoff build-up of pressure raises, when pressure reduction is elevated to a certain degree, can elastic deformation be there is again in microgel, pass through pore constriction, continue to reservoir deep migration, at the next one large venturi, place produces temporary transient shutoff, therefore microgel is a migration in reservoir pore space, shutoff, distortion is passed through, migrate again, the so reciprocal constantly process of shutoff again, thus constantly flow direction variation is carried out to the fluid in reservoir on three dimensions, effectively expand swept volume, improve recovery ratio.
The foregoing is only preferred embodiment of the present invention, not in order to limit the present invention, within the spirit and principles in the present invention all, any amendment done, equivalent replacement, improvement etc., all should be included within protection scope of the present invention.
Claims (7)
1. improve a method for recovery ratio of normal heavy oil reservoirs in water-flooding development, it is characterized in that, comprise the following steps:
(1) microgel and water are configured to concentration 1000-3000mg/l solution;
(2) surfactant and water are configured to concentration 2000-3000mg/l solution;
(3) alter least-squares microgel solution slug and surfactant solution slug successively from well;
Described microgel is acrylamide and methylene diacrylamide copolymer, and described microgel is elastomeric spherical body;
Described surfactant is alkyl benzene sulfonate surfactant;
Described microgel slug and surfactant slug and sequent water flooding slug are periodically alter least-squares, and the injection cycle is 30-100 days.
2. the method for raising recovery ratio of normal heavy oil reservoirs in water-flooding development according to claim 1, is characterized in that: described microgel solution slug injection rate is 0.18 times of oil reservoir voids volume.
3. the method for raising recovery ratio of normal heavy oil reservoirs in water-flooding development according to claim 1, is characterized in that: described surfactant slug injection rate is 0.02 times of oil reservoir voids volume.
4. the method for raising recovery ratio of normal heavy oil reservoirs in water-flooding development according to claim 1, is characterized in that, comprise the following steps:
Described step (3) is: from well, inject following slug successively: inject 0.08 times of movable microgel of oil reservoir voids volume submillimeter level, the movable microgel diameter d of described submillimeter level is 10-100 μm, concentration 1000-3000mg/l; 0.1 times of movable microgel of oil reservoir voids volume micron order, the movable microgel diameter d of described micron order is 1-5 μm, concentration 1000-3000mg/l; 0.02 times of oil reservoir voids volume surfactant, described surfactant concentration is 2000-3000mg/l.
5. the method for raising recovery ratio of normal heavy oil reservoirs in water-flooding development according to claim 1, it is characterized in that, described step (3) is: from well, inject following slug successively: the movable microgel of submillimeter level injecting 0.08 times of oil reservoir voids volume, the diameter d of the movable microgel of described submillimeter level is 10-100 μm, and concentration is 1000-3000mg/l; Be the movable microgel of micron order and the surfactant mixing of 1-5 μm by diameter d according to 4:1 ratio, concentration is 2000mg/l, injects with 0.1 times of oil reservoir voids volume; Inject the movable microgel of submillimeter level of 0.02 times of oil reservoir voids volume, the diameter d of the movable microgel of described submillimeter level is 10-100 μm, and concentration is 1000mg/l.
6. the method for raising recovery ratio of normal heavy oil reservoirs in water-flooding development according to claim 1, is characterized in that: described alkylbenzenesulfonate is neopelex or DBSA ammonium.
7. the method for the raising recovery ratio of normal heavy oil reservoirs in water-flooding development according to any one of claim 1-6, is characterized in that:
Described method is applicable to reservoir temperature 0-120 DEG C, formation water salinity 0-180000mg/l, crude oil underground viscosity 0-150mP.s, permeability 200 × 10
-3μm
2-3000 × 10
-3μm
2oil reservoir.
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