CN104405340A - Polymer flooding oil reservoir microbial plugging removal method - Google Patents
Polymer flooding oil reservoir microbial plugging removal method Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 58
- 229920000642 polymer Polymers 0.000 title claims abstract description 49
- 230000000813 microbial effect Effects 0.000 title abstract 6
- 238000002347 injection Methods 0.000 claims abstract description 182
- 239000007924 injection Substances 0.000 claims abstract description 182
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 82
- 239000012190 activator Substances 0.000 claims abstract description 54
- 238000012360 testing method Methods 0.000 claims abstract description 49
- 238000012216 screening Methods 0.000 claims abstract description 24
- 238000004458 analytical method Methods 0.000 claims abstract description 23
- 230000000694 effects Effects 0.000 claims abstract description 21
- 239000003129 oil well Substances 0.000 claims abstract description 21
- 230000007423 decrease Effects 0.000 claims abstract description 5
- 239000003921 oil Substances 0.000 claims description 74
- 239000011435 rock Substances 0.000 claims description 46
- 238000004088 simulation Methods 0.000 claims description 36
- 238000005457 optimization Methods 0.000 claims description 32
- 230000035699 permeability Effects 0.000 claims description 29
- 241000894006 Bacteria Species 0.000 claims description 26
- 229920002401 polyacrylamide Polymers 0.000 claims description 26
- 239000012530 fluid Substances 0.000 claims description 24
- 238000004519 manufacturing process Methods 0.000 claims description 24
- 241000193375 Bacillus alcalophilus Species 0.000 claims description 22
- 244000005700 microbiome Species 0.000 claims description 20
- 230000008859 change Effects 0.000 claims description 18
- 239000000243 solution Substances 0.000 claims description 14
- 235000013379 molasses Nutrition 0.000 claims description 13
- 230000032683 aging Effects 0.000 claims description 12
- 239000010779 crude oil Substances 0.000 claims description 12
- 239000008398 formation water Substances 0.000 claims description 12
- 238000002513 implantation Methods 0.000 claims description 12
- 239000007788 liquid Substances 0.000 claims description 12
- 229920006395 saturated elastomer Polymers 0.000 claims description 12
- LWIHDJKSTIGBAC-UHFFFAOYSA-K tripotassium phosphate Chemical compound [K+].[K+].[K+].[O-]P([O-])([O-])=O LWIHDJKSTIGBAC-UHFFFAOYSA-K 0.000 claims description 12
- 238000011534 incubation Methods 0.000 claims description 10
- 238000005070 sampling Methods 0.000 claims description 10
- 235000015097 nutrients Nutrition 0.000 claims description 8
- 240000004808 Saccharomyces cerevisiae Species 0.000 claims description 7
- ZPWVASYFFYYZEW-UHFFFAOYSA-L dipotassium hydrogen phosphate Chemical compound [K+].[K+].OP([O-])([O-])=O ZPWVASYFFYYZEW-UHFFFAOYSA-L 0.000 claims description 7
- 238000005516 engineering process Methods 0.000 claims description 7
- 240000008042 Zea mays Species 0.000 claims description 6
- 235000005824 Zea mays ssp. parviglumis Nutrition 0.000 claims description 6
- 235000002017 Zea mays subsp mays Nutrition 0.000 claims description 6
- 235000005822 corn Nutrition 0.000 claims description 6
- 230000005966 endogenous activation Effects 0.000 claims description 6
- 229910000160 potassium phosphate Inorganic materials 0.000 claims description 6
- 235000011009 potassium phosphates Nutrition 0.000 claims description 6
- 238000004454 trace mineral analysis Methods 0.000 claims description 6
- 230000008569 process Effects 0.000 abstract description 9
- 238000010276 construction Methods 0.000 abstract description 3
- 230000008901 benefit Effects 0.000 abstract description 2
- 231100000252 nontoxic Toxicity 0.000 abstract description 2
- 230000003000 nontoxic effect Effects 0.000 abstract description 2
- 230000009467 reduction Effects 0.000 description 20
- 239000009671 shengli Substances 0.000 description 8
- 241000237858 Gastropoda Species 0.000 description 4
- MHAJPDPJQMAIIY-UHFFFAOYSA-N Hydrogen peroxide Chemical compound OO MHAJPDPJQMAIIY-UHFFFAOYSA-N 0.000 description 4
- 238000009825 accumulation Methods 0.000 description 4
- 230000000903 blocking effect Effects 0.000 description 4
- 239000004576 sand Substances 0.000 description 4
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 3
- 239000002253 acid Substances 0.000 description 3
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 239000003795 chemical substances by application Substances 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- OSVXSBDYLRYLIG-UHFFFAOYSA-N dioxidochlorine(.) Chemical compound O=Cl=O OSVXSBDYLRYLIG-UHFFFAOYSA-N 0.000 description 2
- SUKJFIGYRHOWBL-UHFFFAOYSA-N sodium hypochlorite Chemical compound [Na+].Cl[O-] SUKJFIGYRHOWBL-UHFFFAOYSA-N 0.000 description 2
- 239000004155 Chlorine dioxide Substances 0.000 description 1
- 239000005708 Sodium hypochlorite Substances 0.000 description 1
- 208000027418 Wounds and injury Diseases 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 229910001870 ammonium persulfate Inorganic materials 0.000 description 1
- 230000001580 bacterial effect Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 235000019398 chlorine dioxide Nutrition 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 230000006378 damage Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 208000014674 injury Diseases 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 230000002503 metabolic effect Effects 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000002245 particle Substances 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 229960005076 sodium hypochlorite Drugs 0.000 description 1
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/582—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of bacteria
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- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
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- 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- 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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- Micro-Organisms Or Cultivation Processes Thereof (AREA)
Abstract
The invention discloses a polymer flooding oil reservoir microbial plugging removal method. The method specifically comprises the following steps of: screening polymer flooding oil reservoirs and selecting polymer flooding oil reservoirs with oil reservoir temperature being lower than 80DEG C and increase of water injection pressure exceeding 50 percent before and after polymer injection; conducting indigenous microbial plugging removal feasibility analysis, and selecting indigenous plugging removal if indigenous microbial plugging removal conditions are satisfied; conducting exogenous microbes screening if the indigenous microbial plugging removal conditions are not satisfied; optimizing a field injection process to obtain field injection process parameters; conducting field construction and effect tracking. The polymer flooding oil reservoir microbial plugging removal method has the advantages that the method is safe and environmental-friendly and activator used in the method is harmless and nontoxic; the field testing effect is good and the rate of decrease of injection pressure of the oil reservoirs exceeds 50 percent; the construction process is simple, the cost is low, and the effective period is long and is more than 24 months; the acting range is wide, not only can plugging in belts near oil wells be removed, but also plugging at deep positions of the oil reservoirs can be removed, and thus the method can be widely applied to the polymer flooding oil reservoir plugging removal process.
Description
Technical field
The invention belongs to technical field of petroleum extraction, be specifically related to the method for a kind of Polymer Flooding Reservoirs microorganism de-plugging.
Technical background
Oil field is through long-term waterflooding development, define macropore, in order to improve oil recovery factor further, need to inject a large amount of polymer in oil reservoir, but injections a large amount of for a long time can cause the blocking on nearly well and stratum, cause Reservoir Permeability significantly to reduce, cause water injection pressure to raise and be difficult to normal water filling, finally cause stratum energy to be short of, have a strong impact on the subsequent development effect of oil reservoir.
At present, the conventional method removing oil well polymer plugging has following several: (1) hydrogen peroxide (hydrogen peroxide) method, have a large amount of gas during this method process polymer plugging to produce, working security is low, the process later stage has particle to there is the secondary injury causing stratum, dosing is large, and cost is high; (2) ammonium persulfate method, the method need Temperature Treatment more than 60 DEG C, and speed of action is comparatively slow, needs more than 48 hours, and process the cycle that takes effect short, treatment radius is little; (3) chlorine dioxide, sodium-hypochlorite process, the method has that dosing is large, cost is high, process takes effect the shortcoming that the cycle is short and treatment radius is little.The patent " a kind of de-plugging agent for oil-displacing layer and application thereof " of having applied for, patent publication No. CN1363641A, this patented invention is also a kind of de-plugging agent utilizing the chemical agent compositions such as clorox.Application number: CN201010253315.9, " a kind of method utilizing acid-producing bacteria to remove soil-well jam ", this patent is the blocking utilizing the acid such as the Small molecular that produces acetic acid to remove adjacent to oil well area, use acid-producing bacteria in patent instead of there is depolymerization function bacterial classification, and patent is the de-plugging for the nearly wellblock of oil well, instead of for the polymer de-plugging of earth formation deep, the relevant report of the biotechnology de-plugging of the formation blockage still not having polymer flooding to cause at present.
Summary of the invention
The object of the invention is to overcome the deficiencies in the prior art, a kind of layer polymer oil displacing microorganism solution plugging technique and using method thereof are provided, the microorganism and nutrients thereof with solution plugging function are injected in Polymer Flooding Reservoirs by the present invention together, utilize the metabolic activity degradation polymer obstruction of microorganism in oil reservoir, to reach the object of unblocking and injection increasing.
A method for Polymer Flooding Reservoirs microorganism de-plugging, it is characterized in that, the method specifically comprises the following steps:
(1) screening of Polymer Flooding Reservoirs
Choose reservoir temperature and be less than 80 DEG C, and note poly-after water injection pressure more poly-than note before be increased beyond 50% Polymer Flooding Reservoirs.
(2) endogenous microbes de-plugging feasibility analysis
Endogenous microbes de-plugging feasibility analysis concrete steps are: first carry out field sampling, the water sample getting oil well is no less than 1L; Polyacrylamide and activator is added in water sample; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample; If water-like viscosity decreases beyond 80% after endogenous activation, then choose the de-plugging that endogenous microbes carries out oil reservoir.
(3) screening of inoculating microbe
If the viscosity of water sample reduces lower than 80% after above-mentioned endogenous microbes activates, then carry out the screening of inoculating microbe, the concrete steps of inoculating microbe screening are: first carry out field sampling, the water sample getting oil well is no less than 1L; Polyacrylamide, inoculating microbe and nutrients is added in water sample; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample; Filter out the inoculating microbe that water-like viscosity decreases beyond 80%.
(4) on-the-spot injection technology optimization
Activator or inoculating microbe injection rate are optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.02% ~ 0.03%, and injection rate is 0.1PV (voids volume) ~ 0.2PV polyacrylamide solution; 6. inject activator or the microorganism of different amount, cultivate 15d; 7. secondary water drive, detects the injection pressure of rock core, according to the situation of change determination activator of injection pressure or the best injection rate of inoculating microbe.
Activator or inoculating microbe injection mode are optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.02% ~ 0.03%, and injection rate is 0.1PV ~ 0.2PV polyacrylamide solution; 6. inject activator or inoculating microbe in different ways, the injection rate of activator or inoculating microbe is the injection rate of above-mentioned optimization, cultivates 15d; 7. secondary water drive, detects the injection pressure of rock core, according to the situation of change determination activator of injection pressure or the best injection mode of inoculating microbe.
(5) site operation and effect are followed the tracks of
Carry out site operation according to the technological parameter of above-mentioned optimization, after having constructed, carry out effect trace analysis, analyze the change of oil well injection pressure.
Wherein, add polyacrylamide described in step (2) in water sample, its dosage is mass concentration 0.01% ~ 0.03%.
Described activator is made up of molasses, corn steep liquor and potassium phosphate, and mass concentration is respectively 4% ~ 6%, 2% ~ 3% and 0.5% ~ 0.8%.
In water sample, add polyacrylamide described in step (3), its dosage is mass concentration 0.02% ~ 0.04%.
In water sample, add inoculating microbe described in step (3), its dosage is mass concentration 3% ~ 5%.
Described nutrients is made up of molasses, dusty yeast and dipotassium hydrogen phosphate, and mass concentration is respectively 3% ~ 5%, 1% ~ 2% and 0.2% ~ 0.5%.
Described inoculating microbe is the one in bacillus alcalophilus, sulphate-reducing thermophilic bacterium and pseudomonad.
The present invention's advantage compared with prior art and beneficial effect:
(1) safety and environmental protection, the activator used in the present invention is nontoxic;
(2) field experiment is effective, and the injection pressure of oil reservoir reduces amplitude more than 50%;
(3) construction technology is simple, cost is low, period of validity is long, and period of validity is more than 24 months;
(4) scope acted on is wide, not only can remove the blocking of adjacent to oil well area, can also remove the blocking of oil deposit deep part.
Detailed description of the invention
Below in conjunction with specific embodiment, the present invention is described further, but protection scope of the present invention is not limited in this:
Implement 1, for Shengli Oil Field block F
Shengli Oil Field block F is the loose sand oil accumulation of high permeability, medium-high viscosity, high salinity, reservoir temperature 65 DEG C, degree of porosity 34.0%, voids volume 3.6 × 10
4m
3, recoverable reserves 3.6 × 10
4t, this block comes into effect polymer flooding from August, 2009, and implementing injection pressure before polymer flooding is 6.2MPa, ends in December, 2011 injection pressure and rises to 11.3MPa, start in March, 2012 to utilize method of the present invention to carry out the de-plugging of oil reservoir, concrete implementation step is:
(1) screening of Polymer Flooding Reservoirs
Block F reservoir temperature is 65 DEG C, and before and after note is poly-, water injection pressure rises 82.2%, meets the screening conditions of Polymer Flooding Reservoirs.
(2) endogenous microbes de-plugging feasibility analysis
Endogenous microbes de-plugging feasibility analysis concrete steps are: first carry out field sampling, get the water sample 1L of oil well; Add in water sample mass concentration be 0.01% polyacrylamide and mass concentration be 4% molasses, mass concentration be 2% corn steep liquor and mass concentration be the potassium phosphate of 0.5%; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample.
Before cultivating, water-like viscosity is 176mPa.s, and after endogenous activation, water-like viscosity is 32mPa.s, and reduction amplitude is 81.8%, and reduction amplitude more than 80%, then chooses the de-plugging that endogenous microbes carries out oil reservoir.
(3) on-the-spot injection technology optimization
Activator injection amount is optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.02%, and injection rate is 0.1PV polyacrylamide solution; 6. inject the activator of different amount, cultivate 15d; 7. secondary water drive, detect the injection pressure of rock core, according to the best injection rate of the situation of change determination activator of injection pressure, experimental result is as table 1.
The activator rock core injection pressure of the different injection rate of table 1 reduces range value
As can be seen from Table 1 along with the increase injection pressure of activator injection amount is also along with reduction, reduction amplitude is increasing, reducing amplitude when activator injection amount is 0.25PV is 61.1%, reducing amplitude when activator injection amount is 0.30PV is 62.3%, when the injection rate of activator being described more than 0.25PV, reduce changes in amplitude little, therefore, the best injection rate of activator is 0.25PV.
Activator injection method optimizing, its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.03%, and injection rate is 0.2PV polyacrylamide solution; 6. inject activator in different ways, the injection rate of activator is the injection rate of above-mentioned optimization, cultivates 15d; 7. secondary water drive, detect the injection pressure of rock core, according to the best injection mode of the situation of change determination activator of injection pressure, experimental result is in table 2.
Table 2 different activator injection mode rock core injection pressure reduces range value
It is also different that the injection mode that activator is different as can be seen from Table 2 causes injection pressure to reduce amplitude, wherein slug is more maximum than Pressure Drop low amplitude when being 1:2, be 82.3%, therefore, the injection mode of activator is that slug compares 1:2, divide two slugs to inject by activator, each slug injection rate is respectively 0.083PV and 0.167PV.
(4) site operation and effect are followed the tracks of
Carry out site operation according to the technological parameter of above-mentioned optimization, after having constructed, carry out effect trace analysis, analyze the change of oil well injection pressure.
Before enforcement the present invention, the injection pressure of F oil reservoir is 11.3MPa, and after implementing the present invention, the injection pressure of oil reservoir is reduced to 4.8MPa, and reduction amplitude is 57.5%, and daily water-injection rate adds 65 tons, and period of validity is 32 months.
Implement 2, for Shengli Oil Field block L
Shengli Oil Field block L is the loose sand oil accumulation of high permeability, middle low viscosity, middle high salinity, reservoir temperature 72 DEG C, degree of porosity 33.5%, voids volume 3.1 × 10
4m
3, recoverable reserves 2.1 × 10
4t, this block comes into effect polymer flooding from December, 2004, and implementing injection pressure before polymer flooding is 3.1MPa, ends in December, 2007 injection pressure and rises to 7.2MPa, start in June, 2008 to utilize method of the present invention to carry out the de-plugging of oil reservoir, concrete implementation step is:
(1) screening of Polymer Flooding Reservoirs
Block L reservoir temperature is 72 DEG C, and before and after note is poly-, water injection pressure rises 132.3%, meets the screening conditions of Polymer Flooding Reservoirs.
(2) endogenous microbes de-plugging feasibility analysis
Endogenous microbes de-plugging feasibility analysis concrete steps are: first carry out field sampling, get the water sample 1.5L of oil well; Add in water sample mass concentration be 0.02% polyacrylamide and mass concentration be 5% molasses, mass concentration be 2.5% corn steep liquor and mass concentration be the potassium phosphate of 0.6%; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample.
Before cultivating, water-like viscosity is 287mPa.s, and after endogenous activation, water-like viscosity is 47mPa.s, and reduction amplitude is 83.6%, and reduction amplitude more than 80%, then chooses the de-plugging that endogenous microbes carries out oil reservoir.
(3) on-the-spot injection technology optimization
Activator injection amount is optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.03%, and injection rate is 0.2PV polyacrylamide solution; 6. inject activator or the microorganism of different amount, cultivate 15d; 7. secondary water drive, detect the injection pressure of rock core, according to the best injection rate of the situation of change determination activator of injection pressure, experimental result is as table 3.
The activator rock core injection pressure of the different injection rate of table 3 reduces range value
As can be seen from Table 3 along with the increase injection pressure of activator injection amount is also along with reduction, reduction amplitude is increasing, reducing amplitude when activator injection amount is 0.20PV is 84.9%, reducing amplitude when activator injection amount is 0.25PV is 86.1%, when the injection rate of activator being described more than 0.20PV, reduce changes in amplitude little, therefore, the best injection rate of activator is 0.20PV.
Activator injection method optimizing, its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.02%, and injection rate is 0.1PV polyacrylamide solution; 6. inject activator in different ways, the injection rate of activator is the injection rate of above-mentioned optimization, cultivates 15d; 7. secondary water drive, detect the injection pressure of rock core, according to the best injection mode of the situation of change determination activator of injection pressure, experimental result is in table 4.
Table 4 different activator injection mode rock core injection pressure reduces range value
It is also different that the injection mode that activator is different as can be seen from Table 4 causes injection pressure to reduce amplitude, wherein slug is more maximum than Pressure Drop low amplitude when being 1:1, be 85.7%, therefore, the injection mode of activator is that slug compares 1:1, divide two slugs to inject by activator, each slug injection rate is 0.1PV and 0.1PV.
(4) site operation and effect are followed the tracks of
Carry out site operation according to the technological parameter of above-mentioned optimization, after having constructed, carry out effect trace analysis, analyze the change of oil well injection pressure.
Before enforcement the present invention, the injection pressure of L oil reservoir is 7.2MPa, and after implementing the present invention, the injection pressure of oil reservoir is reduced to 3.2MPa, and reduction amplitude is 55.6%, and daily water-injection rate adds 76 tons, and period of validity is 35 months.
Implement 3, for Shengli Oil Field block G
Shengli Oil Field block G is the loose sand oil accumulation of high permeability, medium-high viscosity, high salinity, reservoir temperature 75 DEG C, degree of porosity 33.0%, voids volume 3.2 × 10
5m
3, recoverable reserves 3.2 × 10
5t, this block comes into effect polymer flooding from May, 2006, and implementing injection pressure before polymer flooding is 3.5MPa, ends in December, 2009 injection pressure and rises to 8.2MPa, start in February, 2010 to utilize method of the present invention to carry out the de-plugging of oil reservoir, concrete implementation step is:
(1) screening of Polymer Flooding Reservoirs
Block G reservoir temperature is 75 DEG C, and before and after note is poly-, water injection pressure rises 134.3%, meets the screening conditions of Polymer Flooding Reservoirs.
(2) endogenous microbes de-plugging feasibility analysis
Endogenous microbes de-plugging feasibility analysis concrete steps are: first carry out field sampling, get the water sample 2L of oil well; Add in water sample mass concentration be 0.03% polyacrylamide and mass concentration be 6% molasses, mass concentration be 3% corn steep liquor and mass concentration be the potassium phosphate of 0.8%; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample.
Before cultivating, water-like viscosity is 289mPa.s, and after endogenous activation, water-like viscosity is 123mPa.s, and reduction amplitude is 57.4%, and the amplitude that reduces lower than 80%, then can not choose the de-plugging that endogenous microbes carries out oil reservoir.
(3) screening of inoculating microbe
After above-mentioned endogenous microbes activates, the viscosity of water sample reduces lower than 80%, then carry out the screening of inoculating microbe, and the concrete steps of inoculating microbe screening are: first carry out field sampling, get the water sample 2L of oil well; Add in water sample mass concentration be 0.02% polyacrylamide, mass concentration be 3% inoculating microbe and mass concentration be respectively 3%, 1% and 0.2% molasses, dusty yeast and dipotassium hydrogen phosphate; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample, and experimental result is in table 5.
The different inoculating microbe of table 5 cultivates rear water-like viscosity value and the amplitude of reduction
Before cultivating, water-like viscosity is 213mP.s, after injecting bacillus alcalophilus, sulphate-reducing thermophilic bacterium, pseudomonad cultivation, water-like viscosity is respectively 95mPa.s, 37mPa.s and 63mPa.s, viscosity reduces amplitude difference 55.4%, 82.6% and 70.4%, therefore, sulphate-reducing thermophilic bacterium is selected to carry out the de-plugging of oil reservoir.
(4) on-the-spot injection technology optimization
The optimization of sulphate-reducing thermophilic bacterium injection rate, its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.025%, and injection rate is 0.15PV polyacrylamide solution; 6. inject the sulphate-reducing thermophilic bacterium of different amount, cultivate 15d; 7. secondary water drive, detect the injection pressure of rock core, according to the best injection rate of the situation of change determination sulphate-reducing thermophilic bacterium of injection pressure, experimental result is shown in as table 6.
The sulphate-reducing thermophilic bacterium rock core injection pressure of the different injection rate of table 6 reduces range value
As can be seen from Table 6 along with the increase injection pressure of sulphate-reducing thermophilic bacterium injection rate is also along with reduction, the amplitude of pressure is also along with increase, reducing amplitude when sulphate-reducing thermophilic bacterium injection rate is 0.20PV is 85.0%, reducing amplitude when injection rate is 0.25PV is 87.5%, reducing amplitude when injection rate is 0.30PV is 88.9%, when sulphate-reducing thermophilic bacterium injection rate being described more than 0.20PV, the reduction amplitude of injection pressure is more than 80%, and it is little to reduce changes in amplitude, therefore, the best injection rate of sulphate-reducing thermophilic bacterium is 0.20PV.
Sulphate-reducing thermophilic bacterium injection mode is optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.025%, and injection rate is 0.15PV polyacrylamide solution; 6. inject sulphate-reducing thermophilic bacterium in different ways, the injection rate injecting sulphate-reducing thermophilic bacterium is the injection rate of above-mentioned optimization, cultivates 15d; 7. secondary water drive, detects the injection pressure of rock core, and according to the best injection mode of the situation of change determination sulphate-reducing thermophilic bacterium of injection pressure, table 7 different sulphate-reducing thermophilic bacterium injection mode rock core injection pressure reduces range value.
Table 7 different sulphate-reducing thermophilic bacterium injection mode rock core injection pressure reduces range value
It is also different that the injection mode that sulphate-reducing thermophilic bacterium is different as can be seen from Table 7 causes injection pressure to reduce amplitude, wherein slug is more maximum than Pressure Drop low amplitude when being 1:1, be 84.2%, therefore, the injection mode of sulphate-reducing thermophilic bacterium is that slug compares 1:1, divide two slugs to inject by sulphate-reducing thermophilic bacterium, each slug injection rate is 0.1PV and 0.1PV.
(4) site operation and effect are followed the tracks of
Carry out site operation according to the technological parameter of above-mentioned optimization, after having constructed, carry out effect trace analysis, analyze the change of oil well injection pressure.
Before enforcement the present invention, the injection pressure of oil reservoir is 8.2MPa, and after implementing the present invention, the injection pressure of oil reservoir is reduced to 3.0MPa, and reduction amplitude is 61.0%, and daily water-injection rate increases by 80 tons, and period of validity is 40 months.
Implement 4, for Shengli Oil Field block M
Shengli Oil Field block M is the loose sand oil accumulation of high permeability, medium-high viscosity, high salinity, reservoir temperature 63 DEG C, degree of porosity 32.5%, voids volume 6.8 × 10
5m
3, recoverable reserves 8.1 × 10
5t, this block comes into effect polymer flooding from July, 2005, and implementing injection pressure before polymer flooding is 2.3MPa, ends in December, 2007 injection pressure and rises to 4.7MPa, start in August, 2008 to utilize method of the present invention to carry out the de-plugging of oil reservoir, concrete implementation step is:
(1) screening of Polymer Flooding Reservoirs
Block M reservoir temperature is 63 DEG C, and before and after note is poly-, water injection pressure rises 104.3%, meets the screening conditions of Polymer Flooding Reservoirs.
(2) endogenous microbes de-plugging feasibility analysis
Endogenous microbes de-plugging feasibility analysis concrete steps are: first carry out field sampling, get the water sample 3L of oil well; Add in water sample mass concentration be 0.02% polyacrylamide and mass concentration be 5% molasses, mass concentration be 2.5% corn steep liquor and mass concentration be the potassium phosphate of 0.7%; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample.
Before cultivating, water-like viscosity is 196mPa.s, and after endogenous activation, water-like viscosity is 106mPa.s, and reduction amplitude is 45.9%, and the amplitude that reduces lower than 80%, then can not choose the de-plugging that endogenous microbes carries out oil reservoir.
(3) screening of inoculating microbe
After above-mentioned endogenous microbes activates, the viscosity of water sample reduces lower than 80%, then carry out the screening of inoculating microbe, and the concrete steps of inoculating microbe screening are: first carry out field sampling, get the water sample 3L of oil well; Add in water sample mass concentration be 0.04% polyacrylamide, mass concentration be 5% inoculating microbe and mass concentration be respectively 5%, 2% and 0.5% molasses, dusty yeast and dipotassium hydrogen phosphate; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample, and experimental result is in table 8.
The different inoculating microbe of table 8 cultivates rear water-like viscosity value and the amplitude of reduction
Before cultivating, water-like viscosity is 232mP.s, after injecting bacillus alcalophilus, sulphate-reducing thermophilic bacterium, pseudomonad cultivation, water-like viscosity is respectively 32mPa.s, 58mPa.s and 65mPa.s, viscosity reduces amplitude difference 86.2%, 75.0% and 72.0%, therefore, bacillus alcalophilus is selected to carry out the de-plugging of oil reservoir.
(4) on-the-spot injection technology optimization
The optimization of bacillus alcalophilus injection rate, its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.02%, and injection rate is 0.15PV polyacrylamide solution; 6. inject the bacillus alcalophilus of different amount, cultivate 15d; 7. secondary water drive, detect the injection pressure of rock core, according to the best injection rate of the situation of change determination bacillus alcalophilus of injection pressure, experimental result is as table 9.
The sulphate-reducing thermophilic bacterium rock core injection pressure of the different injection rate of table 9 reduces range value
As can be seen from Table 9 along with the increase injection pressure of bacillus alcalophilus injection rate is also along with reduction, the amplitude of pressure is also along with increase, reducing amplitude when bacillus alcalophilus injection rate is 0.20PV is 52.5%, reducing amplitude when injection rate is 0.25PV is 83.7%, reducing amplitude when injection rate is 0.30PV is 83.3%, when bacillus alcalophilus injection rate being described more than 0.20PV, the reduction amplitude of injection pressure is more than 80%, and it is little to reduce changes in amplitude, therefore, the best injection rate of bacillus alcalophilus is 0.25PV.
Bacillus alcalophilus injection mode is optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.025%, and injection rate is 0.12PV polyacrylamide solution; 6. inject bacillus alcalophilus in different ways, the injection rate injecting bacillus alcalophilus is the injection rate of above-mentioned optimization, cultivates 15d; 7. secondary water drive, detects the injection pressure of rock core, and according to the best injection mode of the situation of change determination bacillus alcalophilus of injection pressure, table 10 different bacillus alcalophilus injection mode rock core reduces range value.
Table 10 different bacillus alcalophilus injection mode rock core injection pressure reduces range value
It is also different that the injection mode that bacillus alcalophilus is different as can be seen from Table 10 causes injection pressure to reduce amplitude, wherein slug is more maximum than Pressure Drop low amplitude when being 1:2, be 81.1%, therefore, the injection mode of bacillus alcalophilus is that slug compares 1:2, divide two slugs to inject by bacillus alcalophilus, each slug injection rate is respectively 0.083PV and 0.167PV.
(4) site operation and effect are followed the tracks of
Carry out site operation according to the technological parameter of above-mentioned optimization, after having constructed, carry out effect trace analysis, analyze the change of oil well injection pressure.
Before enforcement the present invention, the injection pressure of oil reservoir is 4.7MPa, and after implementing the present invention, the injection pressure of oil reservoir is reduced to 1.8MPa, and reduction amplitude is 61.7%, and daily water-injection rate increases by 96 tons, and period of validity is 43 months.
Claims (11)
1. a method for Polymer Flooding Reservoirs microorganism de-plugging, is characterized in that, the method specifically comprises the following steps:
(1) screening of Polymer Flooding Reservoirs
Choose reservoir temperature and be less than 80 DEG C, and note poly-after water injection pressure more poly-than note before be increased beyond 50% Polymer Flooding Reservoirs;
(2) endogenous microbes de-plugging feasibility analysis
Endogenous microbes de-plugging feasibility analysis concrete steps are: first carry out field sampling, the water sample getting oil well is no less than 1L; Polyacrylamide and activator is added in water sample; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample; If water-like viscosity decreases beyond 80% after endogenous activation, then choose the de-plugging that endogenous microbes carries out oil reservoir;
(3) screening of inoculating microbe
If the viscosity of water sample reduces lower than 80% after above-mentioned endogenous microbes activates, then carry out the screening of inoculating microbe, the concrete steps of inoculating microbe screening are: first carry out field sampling, the water sample getting oil well is no less than 1L; Polyacrylamide, inoculating microbe and nutrients is added in water sample; 15d is cultivated under simulating oil deposit temperature condition; Incubation time is complete carries out viscosimetric analysis afterwards to water sample; Filter out the inoculating microbe that water-like viscosity decreases beyond 80%;
(4) on-the-spot injection technology optimization
Activator or inoculating microbe injection rate are optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.02% ~ 0.03%, and injection rate is 0.1PV (voids volume) ~ 0.2PV polyacrylamide solution; 6. inject activator or the microorganism of different amount, cultivate 15d; 7. secondary water drive, detects the injection pressure of rock core, according to the situation of change determination activator of injection pressure or the best injection rate of inoculating microbe;
Activator or inoculating microbe injection mode are optimized, and its optimization method is as follows: 1. load simulation core, and core permeability is the permeability of test block oil reservoir; 2. simulation core vacuumize, saturation testing block formation water; 3. saturation testing block crude oil, is saturated to rock core outlet production fluid oil-containing 100%, aging 7 days of rock core; 4. simulation core water drive, water drive is moisture to testing block production fluid average moisture content value at present to Produced Liquid; 5. implantation quality concentration is 0.02% ~ 0.03%, and injection rate is 0.1PV ~ 0.2PV polyacrylamide solution; 6. inject activator or inoculating microbe in different ways, the injection rate of activator or inoculating microbe is the injection rate of above-mentioned optimization, cultivates 15d; 7. secondary water drive, detects the injection pressure of rock core, according to the situation of change determination activator of injection pressure or the best injection mode of inoculating microbe;
(5) site operation and effect are followed the tracks of
Carry out site operation according to the technological parameter of above-mentioned optimization, after having constructed, carry out effect trace analysis, analyze the change of oil well injection pressure.
2. the method for Polymer Flooding Reservoirs microorganism according to claim 1 de-plugging, is characterized in that, the polyacrylamide in described step (2), and its dosage is mass concentration 0.01% ~ 0.03%.
3. the method for Polymer Flooding Reservoirs microorganism according to claim 1 and 2 de-plugging, is characterized in that, described activator is made up of molasses, corn steep liquor and potassium phosphate, and its mass concentration is respectively 4% ~ 6%, 2% ~ 3% and 0.5% ~ 0.8%.
4. the method for Polymer Flooding Reservoirs microorganism according to claim 1 de-plugging, is characterized in that, the polyacrylamide in described step (3), and its dosage is mass concentration 0.02% ~ 0.04%.
5. the method for the Polymer Flooding Reservoirs microorganism de-plugging according to claim 1 or 4, is characterized in that, described inoculating microbe, its dosage is mass concentration 3% ~ 5%.
6. the method for the Polymer Flooding Reservoirs microorganism de-plugging according to claim 1 or 4, is characterized in that, described inoculating microbe is the one in bacillus alcalophilus, sulphate-reducing thermophilic bacterium and pseudomonad.
7. the method for Polymer Flooding Reservoirs microorganism according to claim 5 de-plugging, is characterized in that, described inoculating microbe is the one in bacillus alcalophilus, sulphate-reducing thermophilic bacterium and pseudomonad.
8. the method for the Polymer Flooding Reservoirs microorganism de-plugging according to claim 1 or 4, it is characterized in that, described nutrients is made up of molasses, dusty yeast and dipotassium hydrogen phosphate, and its mass concentration is respectively 3% ~ 5%, 1% ~ 2% and 0.2% ~ 0.5%.
9. the method for Polymer Flooding Reservoirs microorganism according to claim 5 de-plugging, is characterized in that, described nutrients is made up of molasses, dusty yeast and dipotassium hydrogen phosphate, and its mass concentration is respectively 3% ~ 5%, 1% ~ 2% and 0.2% ~ 0.5%.
10. the method for Polymer Flooding Reservoirs microorganism according to claim 6 de-plugging, is characterized in that, described nutrients is made up of molasses, dusty yeast and dipotassium hydrogen phosphate, and its mass concentration is respectively 3% ~ 5%, 1% ~ 2% and 0.2% ~ 0.5%.
The method of 11. Polymer Flooding Reservoirs microorganism according to claim 7 de-pluggings, it is characterized in that, described nutrients is made up of molasses, dusty yeast and dipotassium hydrogen phosphate, and its mass concentration is respectively 3% ~ 5%, 1% ~ 2% and 0.2% ~ 0.5%.
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