CN107401398A - A kind of method that endogenous microbes displacement of reservoir oil improves oil recovery factor - Google Patents
A kind of method that endogenous microbes displacement of reservoir oil improves oil recovery factor Download PDFInfo
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- CN107401398A CN107401398A CN201710740204.2A CN201710740204A CN107401398A CN 107401398 A CN107401398 A CN 107401398A CN 201710740204 A CN201710740204 A CN 201710740204A CN 107401398 A CN107401398 A CN 107401398A
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- 238000000034 method Methods 0.000 title claims abstract description 31
- 238000011084 recovery Methods 0.000 title claims abstract description 31
- 238000006073 displacement reaction Methods 0.000 title claims abstract description 19
- 239000012190 activator Substances 0.000 claims abstract description 93
- 238000002347 injection Methods 0.000 claims abstract description 46
- 239000007924 injection Substances 0.000 claims abstract description 46
- 238000012360 testing method Methods 0.000 claims abstract description 43
- 230000000694 effects Effects 0.000 claims abstract description 34
- 238000012216 screening Methods 0.000 claims abstract description 26
- 238000005194 fractionation Methods 0.000 claims abstract description 22
- 230000004913 activation Effects 0.000 claims abstract description 20
- 238000005516 engineering process Methods 0.000 claims abstract description 14
- 238000004458 analytical method Methods 0.000 claims abstract description 13
- 238000010521 absorption reaction Methods 0.000 claims abstract description 5
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 62
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 31
- OAICVXFJPJFONN-UHFFFAOYSA-N Phosphorus Chemical compound [P] OAICVXFJPJFONN-UHFFFAOYSA-N 0.000 claims description 31
- 229910052799 carbon Inorganic materials 0.000 claims description 31
- 229910052757 nitrogen Inorganic materials 0.000 claims description 31
- 229910052698 phosphorus Inorganic materials 0.000 claims description 31
- 239000011574 phosphorus Substances 0.000 claims description 31
- 239000011435 rock Substances 0.000 claims description 28
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 28
- 238000002474 experimental method Methods 0.000 claims description 21
- 238000004519 manufacturing process Methods 0.000 claims description 17
- WQZGKKKJIJFFOK-GASJEMHNSA-N Glucose Natural products OC[C@H]1OC(O)[C@H](O)[C@@H](O)[C@@H]1O WQZGKKKJIJFFOK-GASJEMHNSA-N 0.000 claims description 16
- 240000004808 Saccharomyces cerevisiae Species 0.000 claims description 16
- 239000008103 glucose Substances 0.000 claims description 16
- 239000004576 sand Substances 0.000 claims description 16
- 239000007836 KH2PO4 Substances 0.000 claims description 13
- 229910000402 monopotassium phosphate Inorganic materials 0.000 claims description 13
- 239000012530 fluid Substances 0.000 claims description 12
- 230000035699 permeability Effects 0.000 claims description 12
- 238000013508 migration Methods 0.000 claims description 11
- 230000005012 migration Effects 0.000 claims description 11
- 239000003795 chemical substances by application Substances 0.000 claims description 9
- 239000001888 Peptone Substances 0.000 claims description 8
- 108010080698 Peptones Proteins 0.000 claims description 8
- 229930006000 Sucrose Natural products 0.000 claims description 8
- 239000008398 formation water Substances 0.000 claims description 8
- 235000019319 peptone Nutrition 0.000 claims description 8
- 239000005720 sucrose Substances 0.000 claims description 8
- 229910000396 dipotassium phosphate Inorganic materials 0.000 claims description 7
- CZMRCDWAGMRECN-UGDNZRGBSA-N Sucrose Chemical compound O[C@H]1[C@H](O)[C@@H](CO)O[C@@]1(CO)O[C@@H]1[C@H](O)[C@@H](O)[C@H](O)[C@@H](CO)O1 CZMRCDWAGMRECN-UGDNZRGBSA-N 0.000 claims description 6
- 239000000203 mixture Substances 0.000 claims description 6
- 230000018044 dehydration Effects 0.000 claims description 5
- 238000006297 dehydration reaction Methods 0.000 claims description 5
- 239000007788 liquid Substances 0.000 claims description 5
- GNSKLFRGEWLPPA-UHFFFAOYSA-M potassium dihydrogen phosphate Chemical compound [K+].OP(O)([O-])=O GNSKLFRGEWLPPA-UHFFFAOYSA-M 0.000 claims description 4
- 238000002798 spectrophotometry method Methods 0.000 claims description 4
- 125000002791 glucosyl group Chemical group C1([C@H](O)[C@@H](O)[C@H](O)[C@H](O1)CO)* 0.000 claims description 3
- 102000012286 Chitinases Human genes 0.000 claims description 2
- 108010022172 Chitinases Proteins 0.000 claims description 2
- APUPEJJSWDHEBO-UHFFFAOYSA-P ammonium molybdate Chemical compound [NH4+].[NH4+].[O-][Mo]([O-])(=O)=O APUPEJJSWDHEBO-UHFFFAOYSA-P 0.000 claims description 2
- 229940010552 ammonium molybdate Drugs 0.000 claims description 2
- 235000018660 ammonium molybdate Nutrition 0.000 claims description 2
- 239000011609 ammonium molybdate Substances 0.000 claims description 2
- 238000001745 non-dispersive infrared spectroscopy Methods 0.000 claims description 2
- 238000012163 sequencing technique Methods 0.000 claims description 2
- 230000006690 co-activation Effects 0.000 claims 1
- 241000894006 Bacteria Species 0.000 abstract description 5
- 244000005700 microbiome Species 0.000 abstract description 5
- 230000000813 microbial effect Effects 0.000 abstract description 4
- 230000003213 activating effect Effects 0.000 abstract description 3
- 238000013459 approach Methods 0.000 abstract description 2
- 238000002156 mixing Methods 0.000 abstract description 2
- 150000004649 carbonic acid derivatives Chemical class 0.000 abstract 1
- 239000003921 oil Substances 0.000 description 60
- 239000011148 porous material Substances 0.000 description 6
- 229920006395 saturated elastomer Polymers 0.000 description 6
- 230000008569 process Effects 0.000 description 3
- 239000009671 shengli Substances 0.000 description 3
- 239000010779 crude oil Substances 0.000 description 2
- 230000007613 environmental effect Effects 0.000 description 2
- 125000000185 sucrose group Chemical group 0.000 description 2
- 239000004094 surface-active agent Substances 0.000 description 2
- 241000193830 Bacillus <bacterium> Species 0.000 description 1
- 241000589636 Xanthomonas campestris Species 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- WQZGKKKJIJFFOK-VFUOTHLCSA-N beta-D-glucose Chemical compound OC[C@H]1O[C@@H](O)[C@H](O)[C@@H](O)[C@@H]1O WQZGKKKJIJFFOK-VFUOTHLCSA-N 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- ZPWVASYFFYYZEW-UHFFFAOYSA-L dipotassium hydrogen phosphate Chemical compound [K+].[K+].OP([O-])([O-])=O ZPWVASYFFYYZEW-UHFFFAOYSA-L 0.000 description 1
- 238000013332 literature search Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000004060 metabolic process Effects 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 238000009738 saturating Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
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- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Micro-Organisms Or Cultivation Processes Thereof (AREA)
Abstract
The invention belongs to technical field of tertiary oil recovery, and in particular to a kind of method that endogenous microbes displacement of reservoir oil improves oil recovery factor.This method specifically includes following steps：Test the screening of oil reservoir；The screening of activator；The determination of activator chromatographic fractionation effect；The determination of live injection technology；Field test；The statistics of field test results and analysis.The present invention breaks the traditional approach that activator mixing is injected using different activator components are separately injected by the way of, eliminates activator different component and is migrated in oil reservoir the chromatogram effect of absorption；The injection rate of activator is saved, reduces cost；Simultaneously advantageously in the activation efficiency for activating different type endogenous microbes function bacterium, improving activator, so as to further improve the oil displacement efficiency of microorganism.Therefore, present invention is generally applicable in the field test of microbial carbonates.
Description
Technical field
The invention belongs to technical field of tertiary oil recovery, and in particular to a kind of endogenous microbes displacement of reservoir oil improves oil recovery factor
Method.
Background technology
The endogenous microbes displacement of reservoir oil refers to itself microorganism be present using in oil reservoir, is swashed by injecting activator into water injection well
Viable microbial, using microorganism itself and metabolism caused by surface reactive material and biogas effect, improve crude output and
Recovery ratio, it is an environmental protection, the production technique of low cost.
The activator of the endogenous microbes displacement of reservoir oil is mainly made up of carbon source, nitrogen source and phosphorus source three parts, during field conduct
It is to inject oil reservoir after activator is mixed, in the presence of absorption, the effect being detained when being migrated due to activator in oil reservoir, and studies
Show that chromatographic fractionation effect occurs in the carbon source in activator component, nitrogen source and phosphorus source in migration process, change activator
The integrality of composition, activator activation in oil reservoir is deteriorated, have impact on microbial oil displacement effect.Therefore, it is necessary to study
Migration rule of the activator different component in different oil reservoirs, a kind of new activator injection method is found, eliminate activator not
With component chromatographic fractionation effect present in oil reservoir, the activation efficiency of activator is improved, is further effectively activated in oil reservoir
Functional microorganism, displacement of reservoir oil effect is played, ensures field conduct effect.
By literature search, notification number " A of CN 102435720 ", " high efficiency activator of oil reservoir indigenous microbes sieves patent name
Choosing method ", disclose a kind of screening technique of high efficiency activator of oil reservoir indigenous microbes, it is therefore an objective to which how solution quickly filters out
It is adapted to the high-efficient activator component of specific oil reservoir.But the shortcomings that this method, is：(1) screening only has been carried out to activator component,
Migration separation effect of the different component in rock core is not accounted for；(2) institute's screening and activating agent is to microorganism activation effect and activation
Agent component, which is separately injected, to be compared, and activation effect weakens；(3) screening and activating agent process and implementation process complexity are cumbersome, are unfavorable for existing
Implement field.
The content of the invention
It is an object of the invention to overcome the deficiencies in the prior art, and a kind of endogenous microbes displacement of reservoir oil raising crude oil is provided and adopted
The method of yield.The invention, using by way of separately injecting, eliminates by the carbon source in activator component, nitrogen source and phosphorus source
The influence of activator chromatographic fractionation effect in oil reservoir, so as to improve the activation efficiency of activator, finally improve endogenous micro-
The field test results of the biological displacement of reservoir oil.
The invention discloses a kind of method that endogenous microbes displacement of reservoir oil improves oil recovery factor, it is characterised in that specific bag
Following steps are included, but are not limited to following steps：
(1) screening of oil reservoir is tested
The screening of experiment oil reservoir needs to meet following condition：95 DEG C of reservoir temperature ＜, reservoir pressure ＜ 15MPa, oil reservoir ooze
Saturating rate ＞ 50 × 10-3μm2, formation water salinity ＜ 150000mg/L and viscosity of crude ＜ 10000mPas.
(2) screening of activator
Using the endogenous microbes of activation experiment oil reservoir as target, filter out activator carbon source, nitrogen source and phosphorus source composition and
Its component.
(3) determination of activator chromatographic fractionation effect
The determination of activator chromatographic fractionation effect, specific method are as follows：
1. loading 3 groups of the back-up sand rock core of experiment Reservoir Permeability, vacuumize, the stratum water of saturation testing oil reservoir, saturation examination
Test the dehydration degassed crude of oil reservoir；
2. water drive of back-up sand rock core, a water drive is untill with the oil reservoir produced liquid comprehensive water cut of experiment；
3. carbon source, nitrogen source and the phosphorus source of the above-mentioned activator filtered out are injected separately into above-mentioned 3 groups of back-up sand rock cores, to filling out
The production fluid of sandstone heart outlet is continuously detected, the migration rule of analysis carbon source, nitrogen source and phosphorus source in back-up sand rock core, it is determined that
Go out the chromatographic fractionation effect of different activator components.
(4) determination of live injection technology
The determination of live injection technology, specific method are as follows：According to the chromatographic fractionation effect of different activator components, it is determined that
Go out the sequencing and its interlude injected during activator different component field test；Activator carbon source, nitrogen source and phosphorus source
Live injection rate be 80~100m3/d。
(5) field test
Note using high-pressure plunger pump by activator different component according to the injection technology that step (4) determines from experiment oil reservoir
Well injects stratum, and the injection mode of activator carbon source, nitrogen source and phosphorus source is the injection of continous way.
(6) statistics of field test results and analysis
Field test carries out statistics and the analysis of field test results after terminating, calculate the raising recovery ratio value of experiment oil reservoir
And input-output ratio.
The carbon source of described activator is glucose or sucrose；The nitrogen source of described activator is peptone or dusty yeast；
The phosphorus source of described activator is K2HPO4Or KH2PO4。
The measure of the carbon source of described activator is to utilize NDIR line absorption method.
The measure of the nitrogen source of described activator is to utilize alkaline chitinase resolution ultraviolet spectrophotometry.
The measure of the phosphorus source of described activator is to utilize ammonium molybdate spectrophotometric method.
The injection rate of described activator carbon source, nitrogen source and phosphorus source is 80~100m3/d。
The present invention has the following advantages that compared with prior art and beneficial effect：
(1) activator different component separately injects, and breaks the traditional approach of activator mixing injection, eliminates activator not
Migrated with component in oil reservoir the chromatogram effect of absorption；
(2) activator advantageously activates according to different component in sequence and after separated in time injection in raising
The activation efficiency of agent, different type endogenous microbes function bacterium is activated, further plays microbial oil displacement effect.
(3) after activator different component separately injects, chromatographic fractionation effect is avoided to activator component activation effect
Influence, the injection rate of activator is saved, so as to save cost；
(4) specific aim of the method field conduct and workable, and there is cost of winning compared with conventional method
The advantages that low, production fluid is without subsequent treatment, safety and environmental protection.
Brief description of the drawings
Accompanying drawing 1 is activator component moving distribution figure in block A production fluids；
Accompanying drawing 2 is activator component moving distribution figure in block B production fluids；
Accompanying drawing 3 is activator component moving distribution figure in block C production fluids.
Embodiment
With reference to specific embodiment, the present invention is described in further detail：
Embodiment 1：
Test block A overviews in Shengli Oil Field oil recovery factory：60 DEG C, reservoir pressure 10MPa, core intersection 4m of reservoir temperature,
Pore volume 5 × 104m3, permeability 500 × 10-3μm2, formation water salinity 8000mg/L, porosity 23%, viscosity of crude
300mPas, comprehensive water cut 91.2%, recovery percent of reserves 37%, well pattern are 1 mouthful of water injection well, 2 mouthfuls of producing wells.Utilize the present invention's
Method improves the recovery ratio of the oil reservoir, comprises the following steps that：
(1) screening of block is tested
The reservoir temperature for testing block A is 60 DEG C, reservoir pressure 10MPa, Reservoir Permeability are 500 × 10-3μm2, oil
Thickness degree is 4m, formation water salinity 8000mg/L, viscosity of crude 300mPas.Meet the sieve of the experiment oil reservoir of the present invention
Standard is selected, therefore the present invention can be implemented.
(2) screening of activator
Using the ground bacillus of activation experiment oil reservoir production surfactant as target, screening determines activator composition and component
Concentration is glucose 5g/L, peptone 2g/L, K2HPO41.5g/L, bacterium is dense after activation reaches 5.5 × 108Individual/mL.
(3) determination of activator chromatographic fractionation effect
The determination of activator chromatographic fractionation effect, is comprised the following steps that：
1. loading 3 groups of rock core according to reservoir condition, rock core basic demand is permeability 500 × 10-3μm2, porosity 23%,
Saturated pool stratum water, saturated pool dehydration degassed crude；
2. water drive of back-up sand rock core, a water drive recovery percent of reserves 37%, Produced Liquid aqueous 91.2%；
3. the activation agent prescription obtained using screening, above-mentioned 3 groups of back-up sand rock cores are injected separately into by carbon source, nitrogen source and phosphorus source
In, rock core outlet production fluid is continuously detected, the migration rule of analysis carbon source, nitrogen source, phosphorus source in back-up sand rock core, it is determined that
Go out the chromatographic fractionation effect of different activator components.Testing result is as shown in Figure 1.
4. according to carbon source, nitrogen source, phosphorus source Concentration Testing result in production fluid, phosphorus source migration velocity in oil reservoir is most fast, carbon
Source is taken second place, and nitrogen source is most slow, and it is peptone, glucose, K to determine activator different component injection order2HPO4, according to peak-data
Peptone is calculated with glucose at intervals of 0.0208PV, glucose and K2HPO4At intervals of 0.0418PV.
(4) determination of live injection technology
According to physical analogy determine result, determine the injection of activator different component order for peptone, glucose,
K2HPO4, it is 5 × 10 according to reservoir pore volume4m3, injection rate 80m3/ d, calculate peptone is with glucose interval time
0.0208×5×104m3÷80m3/ d=13d, glucose and K2HPO4Interval time is 0.0418 × 5 × 104m3÷80m3/ d=
26d。
(5) field test
Note using high-pressure plunger pump by activator different component according to the injection technology that step (4) determines from experiment oil reservoir
Well injects stratum, peptone, glucose, K2HPO4Injection mode be continous way injection.
(6) statistics of field test results and analysis
Field test terminates rear block comprehensive water cut and drops to 82.3% by 91.2%, aqueous to reduce by 8.9 percentage points, increasing
Produce crude oil 0.32 × 104T, improve recovery ratio 12.8%, input-output ratio 1:4, field test results are good.
Embodiment 2
Test block B overviews in Shengli Oil Field oil recovery factory：65 DEG C, reservoir pressure 10.5MPa of reservoir temperature, core intersection
4.5m, pore volume 7.5 × 104m3, permeability 800 × 10-3μm2, formation water salinity 12563mg/L, porosity 25.0%,
Viscosity of crude 786mPas, comprehensive water cut 88.0%, recovery percent of reserves 34%, well pattern are 1 mouthful of water injection well, 3 mouthfuls of producing wells.Utilize
The method of the present invention improves the recovery ratio of the oil reservoir, comprises the following steps that：
(1) screening of block is tested
The reservoir temperature for testing block B is 65 DEG C, reservoir pressure 10.5MPa, Reservoir Permeability are 800 × 10-3μm2、
Core intersection is 4.5m, formation water salinity 12563mg/L, viscosity of crude 786mPas.Meet the experiment oil reservoir of the present invention
Screening criteria, therefore the present invention can be implemented.
(2) screening of activator
Using the pseudomonad of activation experiment oil reservoir production surfactant as target, screening determines that activator composition and component are dense
Spend for sucrose 3.5g/L, dusty yeast 1.6g/L, KH2PO40.8g/L, endogenous microbes bacterium is dense reaches 7.5 × 10 for activation8Individual/mL
More than.
(3) determination of activator chromatographic fractionation effect
The determination of activator chromatographic fractionation effect, is comprised the following steps that：
1. loading 3 groups of rock core according to reservoir condition, rock core basic demand is permeability 800 × 10-3μm2, porosity 25%,
Saturated pool stratum water, saturated pool dehydration degassed crude；
2. water drive of rock core, a water drive recovery percent of reserves 34%, Produced Liquid aqueous 88.0%；
3. the activation agent prescription obtained using screening, above-mentioned 3 groups of back-up sand rock cores are injected separately into by carbon source, nitrogen source and phosphorus source
In, rock core outlet production fluid is continuously detected, the migration rule of analysis carbon source, nitrogen source, phosphorus source in back-up sand rock core, it is determined that
Go out the chromatographic fractionation effect of different activator components.Testing result is shown in Fig. 2.
4. according to carbon source, nitrogen source, phosphorus source Concentration Testing result in production fluid, nitrogen source migration velocity in oil reservoir is most fast, phosphorus
Source is taken second place, and carbon source is most slow, and it is sucrose, KH to determine activator different component injection order2PO4, dusty yeast, according to peak-data meter
Calculate sucrose and KH2PO4At intervals of 0.0208PV, KH2PO4With dusty yeast at intervals of 0.0211PV.
(4) determination of live injection technology
The result determined according to physical analogy, it is sucrose, KH to determine activator different component injection order2PO4, dusty yeast,
It is 7.5 × 10 according to reservoir pore volume4m3, injection rate 100m3/ d, calculate sucrose and KH2PO4Interval time is 0.0208
×7.5×104m3÷100m3/ d=15.6d, KH2PO4It is 0.0211 × 7.5 × 10 with dusty yeast interval time4m3÷100m3/d
=15.8d.
(5) field test
Note using high-pressure plunger pump by activator different component according to the injection technology that step (4) determines from experiment oil reservoir
Well injects stratum, sucrose, KH2PO4, dusty yeast injection mode be continous way injection.
(6) statistics of field test results and analysis
Field test terminates rear block comprehensive water cut and drops to 77.5% by 88.0%, aqueous to reduce by 10.5 percentage points,
Incremental oil production 0.85 × 104T, improve recovery ratio 16.3%, input-output ratio 1:5.2, field test results are good.
Embodiment 3：
Test block C overviews in Shengli Oil Field oil recovery factory：67 DEG C, reservoir pressure 12.3MPa of reservoir temperature, core intersection
7m, permeability 1200 × 10-3μm2, pore volume 8.2 × 104m3, formation water salinity 7658mg/L, porosity 32.5%, original
Oil viscosity 1256mPas, comprehensive water cut 95.3%, recovery percent of reserves 36.5%, well pattern are 1 mouthful of water injection well, 4 mouthfuls of producing wells.Profit
The recovery ratio of the oil reservoir is improved with the method for the present invention, is comprised the following steps that：
(1) screening of block is tested
The reservoir temperature for testing block C is 67 DEG C, reservoir pressure 12.3MPa, Reservoir Permeability are 1200 × 10-3μm2、
Core intersection is 7m, formation water salinity 7658mg/L, viscosity of crude 1256mPas.Meet the experiment oil reservoir of the present invention
Screening criteria, therefore the present invention can be implemented.
(2) screening of activator
Using the false Xanthomonas campestris of activation experiment oil reservoir generation polymer as target, screening determines activator composition and component
Concentration is glucose 4.5g/L, dusty yeast 2g/L, KH2PO41.2g/L, endogenous microbes bacterium is dense reaches 2.5 × 10 for activation8Individual/
mL。
(3) determination of activator chromatographic fractionation effect
The determination of activator chromatographic fractionation effect, is comprised the following steps that：
1. loading 3 groups of rock core according to reservoir condition, rock core basic demand is permeability 1200 × 10-3μm2, porosity
32.5%, saturated pool stratum water, saturated pool dehydration degassed crude；
2. water drive of rock core, a water drive recovery percent of reserves 36.5%, Produced Liquid aqueous 95.3%；
3. the activation agent prescription obtained using screening, above-mentioned 3 groups of back-up sand rock cores are injected separately into by carbon source, nitrogen source and phosphorus source
In, rock core outlet production fluid is continuously detected, the migration rule of analysis carbon source, nitrogen source, phosphorus source in back-up sand rock core, it is determined that
Go out the chromatographic fractionation effect of different activator components.Testing result is shown in Fig. 3.
4. according to carbon source, nitrogen source, phosphorus source Concentration Testing result in production fluid, phosphorus source migration velocity in oil reservoir is most fast, nitrogen
Source is taken second place, and carbon source is most slow, and it is glucose, dusty yeast, KH to determine activator different component injection order2PO4, according to peak-data
Glucose is calculated with dusty yeast at intervals of 0.0208PV, dusty yeast and KH2PO4At intervals of 0.0208PV.
(4) determination of live injection technology
According to physical analogy determine result, determine the injection of activator different component order for glucose, dusty yeast,
KH2PO4, it is 8.2 × 10 according to reservoir pore volume4m3, injection rate 90m3/ d, calculate glucose and dusty yeast interval time
For 0.0208 × 8.2 × 104m3÷90m3/ d=19d, dusty yeast and KH2PO4Interval time is 0.0208 × 8.2 × 104m3÷
90m3/ d=19d.
(5) field test
Note using high-pressure plunger pump by activator different component according to the injection technology that step (4) determines from experiment oil reservoir
Well injects stratum, glucose, dusty yeast, KH2PO4Injection mode be continous way injection.
(6) statistics of field test results and analysis
Field test terminates rear block comprehensive water cut and drops to 85.0% by 95.3%, aqueous to reduce by 10.3 percentage points,
Incremental oil production 0.88 × 104T, improve recovery ratio 13.5%, input-output ratio 1:4.5, field test results are good.
Claims (6)
1. a kind of method that endogenous microbes displacement of reservoir oil improves oil recovery factor, it is characterised in that following steps are specifically included, but not
It is limited to following steps：
(1) screening of oil reservoir is tested
The screening of experiment oil reservoir needs to meet following condition：95 DEG C of reservoir temperature ＜, reservoir pressure ＜ 15MPa, Reservoir Permeability
＞ 50 × 10-3μm2, formation water salinity ＜ 150000mg/L and viscosity of crude ＜ 10000mPas；
(2) screening of activator
Using the endogenous microbes of activation experiment oil reservoir as target, the composition and its group of activator carbon source, nitrogen source and phosphorus source are filtered out
Point；
(3) determination of activator chromatographic fractionation effect
The determination of activator chromatographic fractionation effect, specific method are as follows：
1. loading 3 groups of the back-up sand rock core of experiment Reservoir Permeability, vacuumize, the stratum water of saturation testing oil reservoir, saturation testing oil
The dehydration degassed crude of Tibetan；
2. water drive of back-up sand rock core, a water drive is untill with the oil reservoir produced liquid comprehensive water cut of experiment；
3. carbon source, nitrogen source and the phosphorus source of the above-mentioned activator filtered out are injected separately into above-mentioned 3 groups of back-up sand rock cores, to back-up sand rock
The production fluid of heart outlet is continuously detected, and the migration rule of analysis carbon source, nitrogen source and phosphorus source in back-up sand rock core, is determined not
The chromatographic fractionation effect of coactivation agent component；
(4) determination of live injection technology
The determination of live injection technology, specific method are as follows：According to the chromatographic fractionation effect of different activator components, determine to swash
The sequencing and its interlude injected during agent different component field test living；Activator carbon source, nitrogen source and phosphorus source show
Field injection rate is 80~100m3/d；
(5) field test
Water injection well using high-pressure plunger pump by activator different component according to the injection technology that step (4) determines from experiment oil reservoir
Stratum is injected, the injection mode of activator carbon source, nitrogen source and phosphorus source is the injection of continous way；
(6) statistics of field test results and analysis
Field test terminate after carry out field test results statistics and analysis, calculate experiment oil reservoir raising recovery ratio value and
Input-output ratio.
2. the method that the endogenous microbes displacement of reservoir oil according to claim 1 improves oil recovery factor, it is characterised in that described
The carbon source of activator is glucose or sucrose, and the nitrogen source of activator is peptone or dusty yeast, and the phosphorus source of activator is K2HPO4Or
KH2PO4。
3. the method that the endogenous microbes displacement of reservoir oil according to claim 1 or 2 improves oil recovery factor, it is characterised in that institute
The measure of the carbon source for the activator stated is to utilize NDIR line absorption method.
4. the method that the endogenous microbes displacement of reservoir oil according to claim 1 or 2 improves oil recovery factor, it is characterised in that institute
The measure of the nitrogen source for the activator stated is to utilize alkaline chitinase resolution ultraviolet spectrophotometry.
5. the method that the endogenous microbes displacement of reservoir oil according to claim 1 or 2 improves oil recovery factor, it is characterised in that institute
The measure of the phosphorus source for the activator stated is to utilize ammonium molybdate spectrophotometric method.
6. the method that the endogenous microbes displacement of reservoir oil according to claim 1 or 2 improves oil recovery factor, it is characterised in that institute
The injection rate of activator carbon source, nitrogen source and the phosphorus source stated is 80~100m3/d。
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710740204.2A CN107401398A (en) | 2017-08-25 | 2017-08-25 | A kind of method that endogenous microbes displacement of reservoir oil improves oil recovery factor |
Applications Claiming Priority (1)
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