CN105735952B - A kind of method that medium to high permeable oil reservoir improves oil recovery factor - Google Patents
A kind of method that medium to high permeable oil reservoir improves oil recovery factor Download PDFInfo
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- 238000011084 recovery Methods 0.000 title claims abstract description 27
- 238000000034 method Methods 0.000 title claims abstract description 22
- 238000002347 injection Methods 0.000 claims abstract description 176
- 239000007924 injection Substances 0.000 claims abstract description 176
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 86
- 229920000642 polymer Polymers 0.000 claims abstract description 57
- 239000004094 surface-active agent Substances 0.000 claims abstract description 56
- 238000012360 testing method Methods 0.000 claims abstract description 26
- 238000012216 screening Methods 0.000 claims abstract description 14
- 238000011156 evaluation Methods 0.000 claims abstract description 6
- 239000003921 oil Substances 0.000 claims description 67
- 229920001222 biopolymer Polymers 0.000 claims description 13
- 239000003876 biosurfactant Substances 0.000 claims description 13
- 230000001419 dependent effect Effects 0.000 claims description 10
- 238000002474 experimental method Methods 0.000 claims description 10
- HVCOBJNICQPDBP-UHFFFAOYSA-N 3-[3-[3,5-dihydroxy-6-methyl-4-(3,4,5-trihydroxy-6-methyloxan-2-yl)oxyoxan-2-yl]oxydecanoyloxy]decanoic acid;hydrate Chemical compound O.OC1C(OC(CC(=O)OC(CCCCCCC)CC(O)=O)CCCCCCC)OC(C)C(O)C1OC1C(O)C(O)C(O)C(C)O1 HVCOBJNICQPDBP-UHFFFAOYSA-N 0.000 claims description 8
- 229930186217 Glycolipid Natural products 0.000 claims description 8
- 239000008398 formation water Substances 0.000 claims description 8
- 239000003795 chemical substances by application Substances 0.000 claims description 6
- 239000007788 liquid Substances 0.000 claims description 5
- 230000003213 activating effect Effects 0.000 claims description 2
- 239000010779 crude oil Substances 0.000 claims description 2
- 238000006073 displacement reaction Methods 0.000 description 7
- 239000002349 well water Substances 0.000 description 7
- 230000035699 permeability Effects 0.000 description 5
- 230000000694 effects Effects 0.000 description 3
- 239000003129 oil well Substances 0.000 description 3
- 239000011148 porous material Substances 0.000 description 3
- 238000011161 development Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000008595 infiltration Effects 0.000 description 2
- 238000001764 infiltration Methods 0.000 description 2
- 108090000765 processed proteins & peptides Proteins 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 230000000813 microbial effect Effects 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
- 235000020681 well water Nutrition 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/164—Injecting CO2 or carbonated water
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/20—Displacing by water
Abstract
The invention belongs to technical field of tertiary oil recovery, and in particular to a kind of method that medium to high permeable oil reservoir improves oil recovery factor, this method specifically include following steps：The screening of oil reservoir；Target reservoir polymer injection well is determined with note surfactant well；The injection stage of polymer；The injection stage of surfactant；The normal water filling stage；Field test results evaluation phase.The present invention has the characteristics that cost of investment is low and the degree of field test raising recovery ratio is high, and field test improves recovery ratio and is more than 15%, and input-output ratio is more than 1:5；The invention has the characteristics that technique simple, specific aim and workable.Therefore, present invention is generally applicable in the field test of medium to high permeable oil reservoir raising recovery ratio.
Description
Technical field
The invention belongs to technical field of tertiary oil recovery, and in particular to a kind of medium to high permeable oil reservoir improves the side of oil recovery factor
Method.
Background technology
With the fast development of China's economy, the demand of oil is increasingly increased, short increasingly severe, and the mesh of oil
Preceding crude oil in China recovery percent of reserves less than 40%, remaining recoverable oil reserves is huge, particularly medium to high permeable oil reservoir, according to system
Meter, medium to high permeable oil reservoir resource account for more than the 60% of total resources, and medium to high permeable oil reservoir passes through long-term waterflooding development, contains to height
In the water interim later stage, production decline is serious, and stable yields difficulty is big, and therefore, there is an urgent need to new raising medium to high permeable oil recovery
Technology.
Medium to high permeable oil reservoir has formd local macropore, conventional water drive is difficult into one since long-period water drive is developed
Step improves recovery ratio, therefore, implements microbial oil displacement currently for middle and high infiltration oil reservoir and generally oil reservoir is carried out first with polymer
Tune is blocked up in deep, carries out surfactant flooding afterwards, the swept volume of oil reservoir is on the one hand improved using deep profile controlling, on the other hand profit
The displacement efficiency of oil reservoir is improved with chemical flooding.But this method is used in experiment block injection of polymer and surfactant and owned
The concurrently injected mode of well, different wells correspond to the oil reservoir of different permeabilities, therefore, inject the polymerization of the relatively low oil reservoir of permeability
On the other hand significantly thing causes the blocking of such oil reservoir, on the one hand causes the waste of polymer and biosurfactant,
Ground influences experiment block entirety recovery ratio degree.
The content of the invention
The purpose of the present invention is provide a kind of medium to high permeable oil reservoir in view of the deficiencies of the prior art and improve oil recovery factor
Method, this method first determine polymer injection well and note surfactant well；Secondly polymer is noted from polymer injection well
Enter, reach effective profile control effect；Again, surfactant and CO are injected from note surfactant well2, the CO of injection2Can have
Effect ground improves the swept volume of surfactant, and surfactant improves the displacement efficiency of oil reservoir；Finally, own from experiment block
Water flooding is injected in water injection well, further improves waterflooding effect, this method has the characteristics that specific aim and workable, not only
The field test results of medium to high permeable oil reservoir can be effectively improved, and cost of investment can be effectively reduced, input-output ratio is high.
A kind of method that medium to high permeable oil reservoir improves oil recovery factor, it is characterised in that specifically include following steps：
(1) screening of oil reservoir
The screening criteria of medium to high permeable oil reservoir is more than 1500 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2、
Viscosity of crude is less than 1200mPa.s and formation water salinity is less than 50000mg/L.
(2) target reservoir polymer injection well and note surfactant well determine
Polymer injection well and note surface-active are divided into according to the water injection well of more major general's target reservoirs of water injection well daily water-injection rate
Agent well, the high well of daily water-injection rate are polymer injection well, and the low well of daily water-injection rate is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 30~50%, remaining well for note surfactant well.
(3) injection stage of polymer
Biopolymer is injected from polymer injection well, the total injection of biopolymer is 0.01~0.03PV, and note is poly-
The amount of compound well injection biopolymer accounts for the ratio-dependent of the total water injection rate of polymer injection well according to its water injection rate.
(4) injection stage of surfactant
After the completion of the injection stage of polymer, biosurfactant and CO are injected from note surfactant well2, biology
The total injection of surfactant is 0.1~0.3PV, and the amount of note surfactant well injection biosurfactant is noted according to it
Water accounts for the ratio-dependent of the note total water injection rate of surfactant well, CO2Injection rate and biosurfactant injection rate ratio are
Mark gas liquid ratio 5~10 under condition:1.
(5) the normal water filling stage
Enter the normal water filling stage after the completion of the injection stage of surfactant, the water injection rate of every mouthful of water injection well is before testing
Water injection rate, field test terminates after normal water filling 12~24 months.
(6) field test results evaluation phase
After the completion of the normal water filling stage, calculate oil increment, improve recovery ratio degree and input-output ratio.
Preferably, the mass concentration of the biopolymer is 0.1~0.3%, molecular weight is 1~5 × 106。
Preferably, the biopolymer is biological polyoses.
Preferably, the biosurfactant is glycolipid or lipopeptid, mass concentration are 0.2~0.5%.
The speed of the normal water filling of the water injection well is 30~200m3/d。
The characteristics of present invention is directed to medium to high permeable water-drive pool, is divided into polymer injection well and note surfactant by water injection well
Well；Secondly biopolymer is injected from polymer injection well, plays the role of effective profile control to oil reservoir；Again, from note surface
Biosurfactant and CO are injected in activating agent well2, the CO of injection2Biosurfactant can be effectively improved involves body
Product, the biosurfactant of injection can effectively improve displacement efficiency；Finally, stratum is injected from experiment all water injection wells of block
Water, further improves waterflood efficiency, and this method has the characteristics that specific aim and workable, can not only effectively improve middle height
The field test results of oil reservoir are permeated, recovery ratio is improved and is more than 15%；And biopolymer and biology can be efficiently reduced
The dosage of surfactant, cost of investment is significantly less, and input-output ratio is high, more than 1:5.
Present invention has the advantages that：
(1) present invention have the characteristics that technique simply, specific aim and workable, be conducive to field popularization application；
(2) the applicable oil reservoir scope of the present invention is wide, is applicable not only to middle and high infiltration water-drive pool, is equally applicable to high temperature oil
Hide；
(3) present invention injects biosurfactant using part well injection biopolymer and another part well
Method, this method can give full play to the respective profile control of injecting and washing oil function and the dosage for being effectively saved injecting, at the same time
The degree that field test improves recovery ratio is high, and field test improves recovery ratio and is more than 15%, and input-output ratio is more than 1:5.
Embodiment
The present invention is described in further detail with reference to specific embodiment, and with reference to data.It is to be understood that these embodiments
It is of the invention solely for the purpose of illustration, rather than limit the scope of the invention in any way.
Embodiment 1
Certain oil field block A, 63 DEG C, reservoir pressure 15.2MPa of reservoir temperature, porosity 34.2%, pore volume 7.5 ×
104m3, permeability 2500 × 10-3μm2, oil in place 3.2 × 104T, ground viscosity of crude 976mPa.s, formation water salinity are
12350mg/L, block average aqueous 97.2% before experiment, 12 mouthfuls of oil well, 6 mouthfuls of well, well daily water-injection rate is shown in Table 1.Utilize this
The method of invention implements live oil displacement test in block A, and specific implementation step is as follows：
The day water of 1 block A wells of table, m3
| Sequence number | Pound sign | Daily water-injection rate | Ranking |
| 1 | A1 | 85 | 4 |
| 2 | A2 | 120 | 1 |
| 3 | A3 | 65 | 5 |
| 4 | A4 | 50 | 6 |
| 5 | A5 | 110 | 2 |
| 6 | A6 | 95 | 3 |
(1) screening of oil reservoir
The screening criteria of oil reservoir is more than 1500 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, viscosity of crude
It is less than 50000mg/L less than 1200mPa.s and formation water salinity, block A meets the screening criteria of oil reservoir, can be in the block
Implement the present invention.
(2) target reservoir polymer injection well and note surfactant well determine
Polymer injection well and note surface-active are divided into according to the water injection well of more major general's target reservoirs of water injection well daily water-injection rate
Agent well, the high well of daily water-injection rate are polymer injection well, and the low well of daily water-injection rate is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 50%, be 3 mouthfuls, be respectively A2、A5And A6, the quantity of note surfactant well is 3
Mouthful, it is respectively A1、A3And A4。
(3) injection stage of polymer
Biological polyoses are injected from polymer injection well, biological polyoses molecular weight is 1~2 × 106, the quality of biological polyoses is dense
The total injection spent for 0.1%, biological polyoses is 0.01PV, is 750m3, the amount of polymer injection well injection biological polyoses is according to it
Water injection rate accounts for the ratio-dependent of the total water injection rate of polymer injection well, A2、A5And A6Well water injection rate accounts for the total water injection rate of polymer injection well
325m3Ratio be respectively 120/325=37.0%, 110/325=33.8%, 95/325=29.2%, A2、A5And A6Well is noted
The amount of biological polyoses is respectively 750 × 37.0%=277.5m3, 750 × 33.8%=253.5m3With 750 × 29.2%=
219m3。
(4) injection stage of surfactant
After the completion of the injection stage of polymer, glycolipid and CO are injected from note surfactant well2, the mass concentration of glycolipid
For 0.2%, the total injection of glycolipid is 0.2PV, is 1.5 × 104m3, the amount of note surfactant well injection glycolipid is according to its note
Water accounts for the ratio-dependent of the note total water injection rate of surfactant well, A1、A3And A4Well water injection rate accounts for the note total water filling of surfactant well
Measure 200m3Ratio be respectively 85/200=42.5%, 65/200=32.5% and 50/200=25.0%, A1、A3And A4Well is noted
The amount of glycolipid is respectively 1.5 × 104× 42.5%=6375m3、1.5×104× 32.5%=4875m3With 1.5 × 104×
25.0%=3750m3, CO2Injection rate and the injection rate ratio of glycolipid are gas liquid ratio 5 under mark condition:1, A1、A3And A4Well injects CO2
Amount be respectively 3.1875 × 104Nm3(mark side), 2.4375 × 104Nm3With 1.875 × 104Nm3。
(5) the normal water filling stage
Enter normal water filling stage, A after the completion of the injection stage of surfactant1、A2、A3、A4、A5、A6The water injection rate of well
It is respectively 85m for the water injection rate before experiment3、120m3、65m3、50m3、110m3And 95m3, scene examination after normal water filling 18 months
Test end.
(6) field test results evaluation phase
After the completion of the normal water filling stage, add up to increase oil 0.528 × 104T, improves recovery ratio 16.5%, and input-output ratio is
1:5.6, aqueous to have dropped 9.3 percentage points, the present invention achieves obvious field test results in the block.
Embodiment 2
Certain oil field block B, 75 DEG C, reservoir pressure 10.5MPa of reservoir temperature, porosity 37.7%, pore volume 9.2 ×
104m3, permeability 2100 × 10-3μm2, oil in place 5.0 × 104T, ground viscosity of crude 875mPa.s, formation water salinity are
9850mg/L, block average aqueous 98.3% before experiment, 8 mouthfuls of oil well, 5 mouthfuls of well, well daily water-injection rate is shown in Table 2.Utilize this hair
Bright method implements live oil displacement test in block B, and specific implementation step is as follows：
The day water of 2 block B wells of table, m3
| Sequence number | Pound sign | Daily water-injection rate | Ranking |
| 1 | B1 | 75 | 5 |
| 2 | B2 | 130 | 1 |
| 3 | B3 | 110 | 2 |
| 4 | B4 | 90 | 3 |
| 5 | B5 | 85 | 4 |
(1) screening of oil reservoir
The screening criteria of oil reservoir is more than 1000 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, viscosity of crude
It is less than 50000mg/L less than 1200mPa.s and formation water salinity, block B meets the screening criteria of oil reservoir, can block reality
Apply the present invention.
(2) target reservoir polymer injection well and note surfactant well determine
Polymer injection well and note surface-active are divided into according to the water injection well of more major general's target reservoirs of water injection well daily water-injection rate
Agent well, the high well of daily water-injection rate are polymer injection well, and the low well of daily water-injection rate is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 40%, be 2 mouthfuls, be respectively B2And B3, the well quantity for noting surfactant is 3
Mouthful, it is respectively B1、B4And B5。
(3) injection stage of polymer
Biological polyoses are injected from polymer injection well, biological polyoses molecular weight is 3~5 × 106, the quality of biological polyoses is dense
The total injection spent for 0.3%, biological polyoses is 0.03PV, is 2760m3, polymer injection well injection biological polyoses amount according to
Its water injection rate accounts for the ratio-dependent of the total water injection rate of polymer injection well, B2And B3Well water injection rate accounts for the total water injection rate 240m of polymer injection well3
Ratio be respectively 130/240=54.2%, 110/240=45.8%, B2And B3The amount of well note biological polyoses is respectively 2760 ×
54.2%=1496m3With 2760 × 45.8%=1264m3。
(4) injection stage of surfactant
After the completion of the injection stage of polymer, lipopeptid and CO are injected from note surfactant well2, lipopeptid mass concentration is
0.5%, the total injection of lipopeptid is 0.1PV, is 9.2 × 103m3, the amount of note surfactant well injection lipopeptid is according to its water filling
Amount accounts for the ratio-dependent of the note total water injection rate of surfactant well, B1、B4And B5Well water injection rate accounts for the note total water injection rate of surfactant well
250m3Ratio be respectively 75/250=30.0%, 90/250=36.0% and 85/250=34.0%, B1、B4And B5Well greasing
The amount of peptide is respectively 9.2 × 103× 30.0%=2760m3、9.2×103× 36.0%=3312m3With 9.2 × 103× 34.0%
=3128m3, CO2Injection rate and the injection rate ratio of lipopeptid are gas liquid ratio 10 under mark condition:1, B1、B4And B5Well injects CO2Amount point
Wei 2.76 × 104Nm3、3.312×104Nm3With 3.128 × 104Nm3。
(5) the normal water filling stage
Enter normal water filling stage, B after the completion of the injection stage of surfactant1、B2、B3、B4、B5The water injection rate of well is examination
Water injection rate before testing, is respectively 75m3、130m3、110m3、90m3And 85m3, field test terminates after normal water filling 24 months.
(6) field test results evaluation phase
After the completion of the normal water filling stage, add up to increase oil 0.91 × 104T, improves recovery ratio 18.2%, input-output ratio 1:
6.3, aqueous to have dropped 12.5 percentage points, the present invention achieves obvious field test results in the block.
Embodiment 3
Certain oil field block C, 58 DEG C, reservoir pressure 13.5MPa of reservoir temperature, porosity 39.7%, pore volume 5.0 ×
104m3, permeability 2800 × 10-3μm2, oil in place 2.5 × 104T, ground viscosity of crude 685mPa.s, formation water salinity are
5860mg/L, block average aqueous 95.8% before experiment, 15 mouthfuls of oil well, 7 mouthfuls of well, well daily water-injection rate is shown in Table 3.Utilize this hair
Bright method implements live oil displacement test in block C, and specific implementation step is as follows：
The day water of 3 block C wells of table, m3
| Sequence number | Pound sign | Daily water-injection rate | Ranking |
| 1 | C1 | 125 | 1 |
| 2 | C2 | 70 | 6 |
| 3 | C3 | 65 | 7 |
| 4 | C4 | 120 | 2 |
| 5 | C5 | 105 | 3 |
| 6 | C6 | 90 | 4 |
| 7 | C7 | 80 | 5 |
(1) screening of oil reservoir
The screening criteria of oil reservoir is more than 1000 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, viscosity of crude
It is less than 50000mg/L less than 1200mPa.s and formation water salinity, block A meets the screening criteria of oil reservoir, can be in this block
Implement the present invention.
(2) target reservoir polymer injection well and note surfactant well determine
Polymer injection well and note surface-active are divided into according to the water injection well of more major general's target reservoirs of water injection well daily water-injection rate
Agent well, the high well of daily water-injection rate are polymer injection well, and the low well of daily water-injection rate is to note surfactant well, polymer injection well
Quantity account for total water injection well quantity ratio be 30%, be 2 mouthfuls, be respectively C1And C4, note surfactant well quantity is 5 mouthfuls, point
Wei not C2、C3、C5、C6And C7。
(3) injection stage of polymer
Biological polyoses are injected from polymer injection well, biological polyoses molecular weight is 2~4 × 106, the quality of biological polyoses is dense
The total injection spent for 0.2%, biological polyoses is 0.02PV, is 1000m3, polymer injection well injection biological polyoses amount according to
Its water injection rate accounts for the ratio-dependent of the total water injection rate of polymer injection well, C1And C4Well water injection rate accounts for the total water injection rate 245m of polymer injection well3
Ratio be respectively 125/245=51.0% and 120/245=49.0%, C1And C4The amount of well note biological polyoses is respectively 1000
× 51.0%=510m3With 1000 × 49.0%=490m3。
(4) injection stage of surfactant
After the completion of the injection stage of polymer, lipopeptid and CO are injected from note surfactant well2, the mass concentration of lipopeptid
For 0.3%, the total injection of lipopeptid is 0.3PV, is 1.5 × 104m3, the amount of note surfactant well injection lipopeptid is according to its note
Water accounts for the ratio-dependent of the note total water injection rate of surfactant well, C2、C3、C5、C6And C7Well water injection rate accounts for note surfactant well
Total water injection rate 410m3Ratio be respectively 70/410=17.1%, 65/410=15.8%, 105/410=25.6%, 90/410
=22.0% and 80/410=19.5%, C2、C3、C5、C6And C7The amount of well greasing peptide is respectively 1.5 × 104× 17.1%=
2565m3、1.5×104× 15.8%=2370m3、1.5×104× 25.6%=3840m3、1.5×104× 22.0%=
3300m3With 1.5 × 104× 19.5%=2925m3, CO2Injection rate and the injection rate ratio of lipopeptid are gas liquid ratio 8 under mark condition:1,
C2、C3、C5、C6And C7Well injects CO2Amount be respectively 2.052 × 104Nm3、1.896×104Nm3、3.072×104Nm3、2.64
×104Nm3With 2.34 × 104Nm3。
(5) the normal water filling stage
Enter normal water filling stage, C after the completion of the injection stage of surfactant1、C2、C3、C4、C5、C6And C7The note of well
Water is the water injection rate before experiment, is respectively 125m3、70m3、65m3、120m3、105m3、90m3And 80m3, normal water filling 12
Field test terminates after month.
(6) field test results evaluation phase
After the completion of the normal water filling stage, add up to increase oil 0.395 × 104T, improves recovery ratio 15.8%, and input-output ratio is
1:6.8, aqueous to have dropped 11.5 percentage points, the present invention achieves obvious field test results in the block.
It is obvious to a person skilled in the art that the invention is not restricted to the details of above-mentioned one exemplary embodiment, Er Qie
In the case of without departing substantially from spirit or essential attributes of the invention, the present invention can be realized in other specific forms.Therefore, no matter
From the point of view of which point, the present embodiments are to be considered as illustrative and not restrictive, and the scope of the present invention is by appended power
Profit requires rather than described above limits, it is intended that all in the implication and scope of the equivalency of claim by falling
Change is included in the present invention.
Moreover, it will be appreciated that although the present specification is described in terms of embodiments, not each embodiment is only wrapped
Containing an independent technical solution, this narrating mode of specification is only that those skilled in the art should for clarity
Using specification as an entirety, the technical solutions in the various embodiments may also be suitably combined, forms those skilled in the art
It is appreciated that other embodiment.
Claims (4)
1. a kind of method that medium to high permeable oil reservoir improves oil recovery factor, it is characterised in that specifically include following steps：
(1) screening of oil reservoir
The screening criteria of medium to high permeable oil reservoir is more than 1500 × 10 for reservoir temperature less than 80 DEG C, Reservoir Permeability-3μm2, crude oil
Viscosity is less than 1200mPa.s and formation water salinity is less than 50000mg/L；
(2) target reservoir polymer injection well and note surfactant well determine
Polymer injection well and note surfactant well are divided into according to the water injection well of more major general's target reservoirs of water injection well daily water-injection rate,
The high well of daily water-injection rate is polymer injection well, and the low well of daily water-injection rate is to note surfactant well, the number of polymer injection well
The ratio that amount accounts for total water injection well quantity is 30~50%, remaining well is note surfactant well；
(3) injection stage of polymer
Inject biopolymer from polymer injection well, the total injection of biopolymer is 0.01~0.03PV, polymer injection
The amount of well injection biopolymer accounts for the ratio-dependent of the total water injection rate of polymer injection well according to its water injection rate；
(4) injection stage of surfactant
After the completion of the injection stage of polymer, biosurfactant and CO are injected from note surfactant well2, biological surface
The total injection of activating agent is 0.1~0.3PV, and the amount of note surfactant well injection biosurfactant is according to its water injection rate
Account for the ratio-dependent of the note total water injection rate of surfactant well, CO2Injection rate and biosurfactant injection rate ratio are mark condition
Lower gas liquid ratio 5~10:1；
(5) the normal water filling stage
Enter the normal water filling stage after the completion of the injection stage of surfactant, the water injection rate of every mouthful of water injection well is the note before experiment
Water, field test terminates after normal water filling 12~24 months；
(6) field test results evaluation phase
After the completion of the normal water filling stage, calculate oil increment, improve recovery ratio degree and input-output ratio.
2. the method that a kind of medium to high permeable oil reservoir according to claim 1 improves oil recovery factor, it is characterised in that described
Biopolymer mass concentration be 0.1~0.3%, molecular weight be 1~5 × 106。
3. the method that a kind of medium to high permeable oil reservoir according to claim 2 improves oil recovery factor, it is characterised in that described
Biopolymer be biological polyoses.
4. the method that a kind of medium to high permeable oil reservoir according to claim 1 improves oil recovery factor, it is characterised in that described
Biosurfactant be glycolipid or lipopeptid, mass concentration are 0.2~0.5%.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610109066.3A CN105735952B (en) | 2016-02-29 | 2016-02-29 | A kind of method that medium to high permeable oil reservoir improves oil recovery factor |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610109066.3A CN105735952B (en) | 2016-02-29 | 2016-02-29 | A kind of method that medium to high permeable oil reservoir improves oil recovery factor |
Publications (2)
| Publication Number | Publication Date |
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| CN107795306B (en) * | 2016-08-30 | 2020-03-27 | 中国石油化工股份有限公司 | Endogenous microbial oil recovery method for low-permeability oil reservoir |
| CN107762446A (en) * | 2017-11-28 | 2018-03-06 | 烟台史密得机电设备制造有限公司 | A kind of method of vinasse and distillery waste water comprehensive utilization |
| CN114427399A (en) * | 2020-09-21 | 2022-05-03 | 中国石油化工股份有限公司 | Method for improving recovery ratio of microbial oil displacement of medium-high permeability reservoir |
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