CN114427400B - Method for improving development effect of biological limestone oil reservoir by utilizing acidogenic microorganisms - Google Patents
Method for improving development effect of biological limestone oil reservoir by utilizing acidogenic microorganisms Download PDFInfo
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- 244000005700 microbiome Species 0.000 title claims abstract description 101
- 238000000034 method Methods 0.000 title claims abstract description 73
- 230000000694 effects Effects 0.000 title claims abstract description 61
- 235000019738 Limestone Nutrition 0.000 title claims abstract description 46
- 239000006028 limestone Substances 0.000 title claims abstract description 46
- 238000011161 development Methods 0.000 title claims abstract description 23
- 230000002053 acidogenic effect Effects 0.000 title claims description 18
- 238000012360 testing method Methods 0.000 claims abstract description 146
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 140
- 239000000243 solution Substances 0.000 claims abstract description 120
- 235000015097 nutrients Nutrition 0.000 claims abstract description 117
- 238000002347 injection Methods 0.000 claims abstract description 111
- 239000007924 injection Substances 0.000 claims abstract description 111
- 239000002253 acid Substances 0.000 claims abstract description 104
- 238000012216 screening Methods 0.000 claims abstract description 45
- 239000000843 powder Substances 0.000 claims abstract description 44
- 238000011084 recovery Methods 0.000 claims abstract description 44
- 230000008569 process Effects 0.000 claims abstract description 28
- 230000007797 corrosion Effects 0.000 claims abstract description 27
- 238000005260 corrosion Methods 0.000 claims abstract description 27
- 238000011156 evaluation Methods 0.000 claims abstract description 19
- 239000003921 oil Substances 0.000 claims description 124
- 235000019198 oils Nutrition 0.000 claims description 124
- VWDWKYIASSYTQR-UHFFFAOYSA-N sodium nitrate Chemical compound [Na+].[O-][N+]([O-])=O VWDWKYIASSYTQR-UHFFFAOYSA-N 0.000 claims description 68
- 241000186660 Lactobacillus Species 0.000 claims description 42
- 229940039696 lactobacillus Drugs 0.000 claims description 42
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 40
- 241000589220 Acetobacter Species 0.000 claims description 38
- 239000004317 sodium nitrate Substances 0.000 claims description 34
- 235000010344 sodium nitrate Nutrition 0.000 claims description 34
- 241000193401 Clostridium acetobutylicum Species 0.000 claims description 30
- 241000194020 Streptococcus thermophilus Species 0.000 claims description 30
- JVTAAEKCZFNVCJ-UHFFFAOYSA-N lactic acid Chemical compound CC(O)C(O)=O JVTAAEKCZFNVCJ-UHFFFAOYSA-N 0.000 claims description 30
- SURQXAFEQWPFPV-UHFFFAOYSA-L iron(2+) sulfate heptahydrate Chemical compound O.O.O.O.O.O.O.[Fe+2].[O-]S([O-])(=O)=O SURQXAFEQWPFPV-UHFFFAOYSA-L 0.000 claims description 24
- 239000007788 liquid Substances 0.000 claims description 24
- 229940050906 magnesium chloride hexahydrate Drugs 0.000 claims description 24
- DHRRIBDTHFBPNG-UHFFFAOYSA-L magnesium dichloride hexahydrate Chemical compound O.O.O.O.O.O.[Mg+2].[Cl-].[Cl-] DHRRIBDTHFBPNG-UHFFFAOYSA-L 0.000 claims description 24
- 229910000403 monosodium phosphate Inorganic materials 0.000 claims description 24
- 235000019799 monosodium phosphate Nutrition 0.000 claims description 24
- AJPJDKMHJJGVTQ-UHFFFAOYSA-M sodium dihydrogen phosphate Chemical compound [Na+].OP(O)([O-])=O AJPJDKMHJJGVTQ-UHFFFAOYSA-M 0.000 claims description 24
- AKHNMLFCWUSKQB-UHFFFAOYSA-L sodium thiosulfate Chemical compound [Na+].[Na+].[O-]S([O-])(=O)=S AKHNMLFCWUSKQB-UHFFFAOYSA-L 0.000 claims description 24
- 235000019345 sodium thiosulphate Nutrition 0.000 claims description 24
- 238000006243 chemical reaction Methods 0.000 claims description 22
- 230000018109 developmental process Effects 0.000 claims description 21
- 239000010779 crude oil Substances 0.000 claims description 20
- 239000011780 sodium chloride Substances 0.000 claims description 20
- 238000005303 weighing Methods 0.000 claims description 19
- 230000003628 erosive effect Effects 0.000 claims description 18
- 239000011435 rock Substances 0.000 claims description 17
- 239000004310 lactic acid Substances 0.000 claims description 15
- 235000014655 lactic acid Nutrition 0.000 claims description 15
- 241000894006 Bacteria Species 0.000 claims description 14
- 230000033558 biomineral tissue development Effects 0.000 claims description 14
- 230000035699 permeability Effects 0.000 claims description 13
- 239000011148 porous material Substances 0.000 claims description 13
- 241000186000 Bifidobacterium Species 0.000 claims description 12
- UIIMBOGNXHQVGW-DEQYMQKBSA-M Sodium bicarbonate-14C Chemical compound [Na+].O[14C]([O-])=O UIIMBOGNXHQVGW-DEQYMQKBSA-M 0.000 claims description 12
- 238000012258 culturing Methods 0.000 claims description 12
- 229920006395 saturated elastomer Polymers 0.000 claims description 12
- 238000000967 suction filtration Methods 0.000 claims description 12
- 238000002474 experimental method Methods 0.000 claims description 11
- 239000001888 Peptone Substances 0.000 claims description 10
- 108010080698 Peptones Proteins 0.000 claims description 10
- 240000004808 Saccharomyces cerevisiae Species 0.000 claims description 10
- 235000015278 beef Nutrition 0.000 claims description 10
- ZPWVASYFFYYZEW-UHFFFAOYSA-L dipotassium hydrogen phosphate Chemical compound [K+].[K+].OP([O-])([O-])=O ZPWVASYFFYYZEW-UHFFFAOYSA-L 0.000 claims description 10
- 229910000402 monopotassium phosphate Inorganic materials 0.000 claims description 10
- 235000019796 monopotassium phosphate Nutrition 0.000 claims description 10
- 235000019319 peptone Nutrition 0.000 claims description 10
- PJNZPQUBCPKICU-UHFFFAOYSA-N phosphoric acid;potassium Chemical compound [K].OP(O)(O)=O PJNZPQUBCPKICU-UHFFFAOYSA-N 0.000 claims description 10
- 235000012424 soybean oil Nutrition 0.000 claims description 10
- 239000003549 soybean oil Substances 0.000 claims description 10
- 238000011065 in-situ storage Methods 0.000 claims description 8
- 230000009467 reduction Effects 0.000 claims description 8
- 230000032683 aging Effects 0.000 claims description 7
- 238000001816 cooling Methods 0.000 claims description 7
- 238000009738 saturating Methods 0.000 claims description 7
- 239000006228 supernatant Substances 0.000 claims description 7
- 230000003137 locomotive effect Effects 0.000 claims description 4
- 238000012544 monitoring process Methods 0.000 claims 1
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 description 24
- 230000020477 pH reduction Effects 0.000 description 18
- 235000017557 sodium bicarbonate Nutrition 0.000 description 12
- 229910000030 sodium bicarbonate Inorganic materials 0.000 description 12
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 10
- 238000000855 fermentation Methods 0.000 description 9
- 230000004151 fermentation Effects 0.000 description 9
- 239000012530 fluid Substances 0.000 description 8
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 7
- 230000008859 change Effects 0.000 description 7
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 description 6
- 235000010216 calcium carbonate Nutrition 0.000 description 5
- 229910000019 calcium carbonate Inorganic materials 0.000 description 5
- 238000001035 drying Methods 0.000 description 5
- 239000008398 formation water Substances 0.000 description 5
- 238000003860 storage Methods 0.000 description 5
- 230000006378 damage Effects 0.000 description 4
- 239000003129 oil well Substances 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
- 150000007513 acids Chemical class 0.000 description 3
- 230000000903 blocking effect Effects 0.000 description 3
- 230000007547 defect Effects 0.000 description 3
- 239000003112 inhibitor Substances 0.000 description 3
- 230000004060 metabolic process Effects 0.000 description 3
- 239000002245 particle Substances 0.000 description 3
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 2
- 241000193830 Bacillus <bacterium> Species 0.000 description 2
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 description 2
- NBIIXXVUZAFLBC-UHFFFAOYSA-N Phosphoric acid Chemical compound OP(O)(O)=O NBIIXXVUZAFLBC-UHFFFAOYSA-N 0.000 description 2
- 239000000654 additive Substances 0.000 description 2
- 230000000996 additive effect Effects 0.000 description 2
- 150000003863 ammonium salts Chemical class 0.000 description 2
- 159000000007 calcium salts Chemical class 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 239000001963 growth medium Substances 0.000 description 2
- -1 lactate compound Chemical class 0.000 description 2
- 230000007774 longterm Effects 0.000 description 2
- 159000000003 magnesium salts Chemical class 0.000 description 2
- 239000011159 matrix material Substances 0.000 description 2
- BDAGIHXWWSANSR-UHFFFAOYSA-N methanoic acid Natural products OC=O BDAGIHXWWSANSR-UHFFFAOYSA-N 0.000 description 2
- 238000013508 migration Methods 0.000 description 2
- 230000005012 migration Effects 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 239000003381 stabilizer Substances 0.000 description 2
- 230000000087 stabilizing effect Effects 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- POAOYUHQDCAZBD-UHFFFAOYSA-N 2-butoxyethanol Chemical compound CCCCOCCO POAOYUHQDCAZBD-UHFFFAOYSA-N 0.000 description 1
- OSWFIVFLDKOXQC-UHFFFAOYSA-N 4-(3-methoxyphenyl)aniline Chemical compound COC1=CC=CC(C=2C=CC(N)=CC=2)=C1 OSWFIVFLDKOXQC-UHFFFAOYSA-N 0.000 description 1
- MIMUSZHMZBJBPO-UHFFFAOYSA-N 6-methoxy-8-nitroquinoline Chemical compound N1=CC=CC2=CC(OC)=CC([N+]([O-])=O)=C21 MIMUSZHMZBJBPO-UHFFFAOYSA-N 0.000 description 1
- 244000283763 Acetobacter aceti Species 0.000 description 1
- 235000007847 Acetobacter aceti Nutrition 0.000 description 1
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 description 1
- KWIUHFFTVRNATP-UHFFFAOYSA-O N,N,N-trimethylglycinium Chemical compound C[N+](C)(C)CC(O)=O KWIUHFFTVRNATP-UHFFFAOYSA-O 0.000 description 1
- ABLZXFCXXLZCGV-UHFFFAOYSA-N Phosphorous acid Chemical compound OP(O)=O ABLZXFCXXLZCGV-UHFFFAOYSA-N 0.000 description 1
- 239000002535 acidifier Substances 0.000 description 1
- 239000000853 adhesive Substances 0.000 description 1
- 230000001070 adhesive effect Effects 0.000 description 1
- 229910000147 aluminium phosphate Inorganic materials 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- 235000019270 ammonium chloride Nutrition 0.000 description 1
- 230000002579 anti-swelling effect Effects 0.000 description 1
- 229960003237 betaine Drugs 0.000 description 1
- 150000001735 carboxylic acids Chemical class 0.000 description 1
- 230000005465 channeling Effects 0.000 description 1
- 239000002738 chelating agent Substances 0.000 description 1
- 239000003795 chemical substances by application Substances 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 235000019253 formic acid Nutrition 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 150000003893 lactate salts Chemical class 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 231100000252 nontoxic Toxicity 0.000 description 1
- 230000003000 nontoxic effect Effects 0.000 description 1
- 125000001477 organic nitrogen group Chemical group 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000000704 physical effect Effects 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 239000002994 raw material Substances 0.000 description 1
- 230000036632 reaction speed Effects 0.000 description 1
- 230000035484 reaction time Effects 0.000 description 1
- 239000012744 reinforcing agent Substances 0.000 description 1
- 239000013049 sediment Substances 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 230000001988 toxicity Effects 0.000 description 1
- 231100000419 toxicity Toxicity 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
-
- 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
- E21B47/00—Survey of boreholes or wells
Landscapes
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Measuring Or Testing Involving Enzymes Or Micro-Organisms (AREA)
- Micro-Organisms Or Cultivation Processes Thereof (AREA)
- Apparatus Associated With Microorganisms And Enzymes (AREA)
Abstract
The invention belongs to the technical field of tertiary oil recovery, and relates to a method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms. The method comprises the following steps: screening test oil reservoirs, wherein indexes of the test oil reservoir screening comprise the content of biological limestone in the test oil reservoir, and the oil reservoir with the biological limestone content being more than 15% is screened; screening of acid-producing functional microorganisms of the test oil reservoirs, wherein the screening basis of the acid-producing functional microorganisms is pH value, caCO 3 powder quality loss and corrosion rate; determining a test oil deposit on-site injection process, wherein the test oil deposit on-site injection process comprises the injection amount, injection mode and well closing culture time of acid-producing functional microorganisms and nutrient solution; and (5) field test and effect evaluation. The invention has the advantages of simple process, simple and convenient operation and low cost, and simultaneously has the advantages of good field test effect, the effective period is longer than 5 years, the water injection pressure value is reduced by more than 30%, the water injection quantity is increased by more than 50%, and the field test improves the recovery ratio by more than 15%.
Description
Technical Field
The invention belongs to the technical field of tertiary oil recovery, and relates to a method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms.
Background
The biological limestone oil reservoir is mainly biological clastic limestone, the lithology is complex, spiral cavities and holes in the reservoir develop, and acidification is a widely used yield increasing means in the biological limestone oil reservoir. The oil well is generally acidized and put into production, and the water well is generally required to be acidized and unblocked for a plurality of times due to poor water quality and poor physical properties of a reservoir. In the later stage, the water content of the oil well rises fast due to the development of the reservoir microcracks, the water channeling is serious, and the development effect is improved by adopting multi-turn profile control and acidification.
Current acidification techniques generally include tubular column acidification and fixed tubular column acidification, with acid materials generally having a strong and weak acid separation. The acidification of the movable pipe column requires operation, is time-consuming and high in cost, has certain toxicity and strong corrosion to strong acid, has large acid liquor flowback and treatment difficulty and small treatment radius, and is quick in reaction and easy to cause secondary precipitation to pollute the stratum again. The operation can be omitted by acidizing the fixed pipe column, but the type, the using amount, the injection speed and the reaction time of the acid liquid are all required to be matched with the oil reservoir, especially the biological limestone oil reservoir, the heterogeneity is stronger, the sensitivity of the oil reservoir is strong, the matching difficulty is high, the effect is difficult to ensure, the high temperature of the acid liquid is not resistant, and the acid liquid has certain corrosion to the pipe column. In recent years, an acidification mode matched with pulse on the basis of immovable acidification mainly solves the problem of small radius of immovable acidification treatment, has the defect of conventional acidification, and is easy to damage a casing. Long-term acidification can only solve the problem of blockage in near-wellbore zones, and has the advantages of high cost, poorer and worse effects, and poor overall development effect of the biological limestone oil reservoir, so other methods for improving the recovery ratio are urgently needed.
CN104277820a discloses a high-temperature sandstone oil reservoir retarded acid, which is prepared from the following raw materials in parts by weight: 5-15 parts of hydrochloric acid, 10-25 parts of lactate compounds, 0.5-5 parts of citric acid, 2-8 parts of ammonium bifluoride, 2-5 parts of high-temperature corrosion inhibitor, 0.5-2 parts of surfactant and 40-80 parts of water. The lactate compound can slowly hydrolyze at a higher temperature to generate lactic acid, which is not only a good retarded acid, but also a chelating agent, and the solubility of calcium salt and magnesium salt in water is higher, so that the invention can meet the acidification requirement of the matrix at the deep part of the high-temperature stratum, overcomes the defect that the sediment of calcium salt and magnesium salt is easy to generate to block the stratum when the content of formic acid and acetic acid is increased, reduces the corrosion to an oil well tubular column, reduces the damage to the stratum, slows down the reaction speed, and enhances the acidification effect of the matrix at the deep part of the stratum.
CN110791279a discloses a high-viscosity strong corrosion acid solution system of a low-permeability sandstone oil reservoir, which comprises the following components in percentage by mass: 6 to 12 percent of hydrochloric acid, 1 to 3 percent of betaine, 4 to 8 percent of reinforcing agent, 0.05 to 0.2 percent of citric acid, 0.5 to 2 percent of ammonium chloride, 0.5 to 2 percent of corrosion inhibitor, 0.1 to 0.4 percent of cleanup additive, 0.05 to 0.2 percent of demulsifier and the balance of water, wherein the sum of the components is 100 percent; in the acidizing process of the acid liquor system, the viscosity of the acid liquor is increased, so that the acid liquor filtration is reduced, more fresh acid is forced to enter the deep part of the stratum, the effective acting distance of the acid liquor is increased, and after the acidizing is finished, high-viscosity fluid is automatically broken into low-viscosity fluid when encountering crude oil in the stratum, so that the stratum is not damaged secondarily.
CN104109528a discloses a sand stabilizing, blocking removing and acidifying liquid and a preparation method thereof, which belong to the technical field of petroleum exploitation. The sand stabilizing and blocking removing acidizing fluid consists of the following components in percentage by weight: 6 to 15 percent of hydrochloric acid, 3 to 10 percent of fluoboric acid, 0.5 to 5 percent of hydrofluoric acid, 0.5 to 5 percent of anti-swelling agent, 0.5 to 5 percent of IS-130 corrosion inhibitor, 0.5 to 5 percent of SCA iron ion stabilizer, 0.5 to 5 percent of XT-05 cleanup additive, 0.5 to 5 percent of ethylene glycol monobutyl ether, 5 to 15 percent of XT-23 sand-inhibiting stabilizer and the balance of water; the method is mainly used for the stratum of a loose sandstone reservoir, can remove inorganic blockage of the stratum, forms an adhesive cover at the contact point and the surface of fine sandstone and clay particles, consolidates skeleton grits, inhibits particle migration, and reduces the damage of stratum sand and particle migration blockage to the reservoir caused by the loose rock skeleton in the operation process of various measures, thereby prolonging the effective period of the measures, simplifying the construction process, reducing the operation cost and improving the comprehensive effect of loose sandstone reservoir exploitation.
CN101089118 discloses an acidulant composition comprising a component a, a component B, a component D and water, the component a being at least one selected from HCl, phosphoric acid, HNO 3, organic carboxylic acids, the component B being HF or a compound capable of generating HF, the component C being an organic amine phosphonic acid, the component D being an organic nitrogen-containing compound capable of forming an ammonium salt with an acid or an ammonium salt thereof. The acidifier composition provided by the invention can solve the problem of deep blockage of a sandstone reservoir with low permeability and high mineralization degree, which is easy to scale, can thoroughly remove the blockage near the well bore of an oil well and a water well and at the deep part of a stratum, has more obvious blockage removing effect on the reservoir with high mineralization degree, which is easy to scale, and has remarkable scale preventing performance, and the acidification validity period is greatly prolonged.
The above patents propose various methods for reservoir or well acidizing, but also suffer from the following drawbacks or deficiencies: all the acids are chemical acids, and the use of the chemical acids has good acidizing effect on sandstone oil reservoirs but poor acidizing effect on limestone oil reservoirs; the retarded acid or the acid liquor is not resistant to high temperature, the adaptability to medium-high temperature oil reservoirs is poor, and meanwhile, the acid liquor has certain corrosion and damage to a pipe column or a casing; long-term acidification can only solve the problem of blockage in near wellbore zones, and has high cost and poorer effect.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provide a method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms.
Therefore, in order to achieve the above object, the present invention discloses a method for improving the development effect of a biological limestone oil reservoir by using acid-producing microorganisms, the method comprising the steps of:
(1) Screening of test reservoirs
The index of the test oil reservoir screening comprises the content of the biological limestone of the test oil reservoir, and the oil reservoir with the biological limestone content being more than 15% is screened.
(2) Screening of test reservoir acid producing functional microorganisms
The screening of acid-producing functional microorganisms is based on the pH value, caCO 3 powder mass loss and corrosion rate.
(3) Determination of test reservoir in situ injection Process
The on-site injection process of the test oil reservoir comprises the injection amount, injection mode and well closing culture time of acid-producing functional microorganisms and nutrient solution thereof.
(4) Site test and effect evaluation
Injecting acid-producing functional microorganisms and nutrient solution into a test oil reservoir, injecting water normally for 5-7d after injection, closing the well for culture, recovering water injection, and evaluating the effect after the test is finished.
Compared with the prior art, the invention has the following advantages:
(1) The acid-producing functional microorganisms are firstly utilized to act on the biological limestone oil reservoir, so that the pore structure of the limestone oil reservoir is changed, the diversion capacity is improved, the injection pressure of the water well is reduced, and the injection quantity of the water well is increased; meanwhile, acid generated by metabolism of acid-producing functional microorganisms can act on scale or inorganic scale of an oil-water well, so that the purpose of blocking removal is achieved.
(2) The acid generated by microorganism metabolism has long effective period, and the problem of high treatment cost caused by conventional acidification multiple operations is avoided; the acid produced by microorganism metabolism is safe and reliable, has no corrosiveness, is nontoxic and harmless to oil reservoirs and pipe columns, and does not influence the subsequent sewage treatment.
(3) The method is used for injecting the water from the water injection well of the test oil reservoir, does not need a movable pipe column, has the advantages of simple process, simple and convenient operation, low cost and good field test effect, has the effective period of more than 5 years, reduces the water injection pressure value by more than 30%, increases the water injection amount by more than 50%, and improves the recovery ratio by more than 15% in the field test.
The specific embodiment is as follows:
The endpoints and any values of the ranges disclosed herein are not limited to the precise range or value, and are understood to encompass values approaching those ranges or values. For numerical ranges, one or more new numerical ranges may be found between the endpoints of each range, between the endpoint of each range and the individual point value, and between the individual point value, in combination with each other, and are to be considered as specifically disclosed herein.
The invention discloses a method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms, which comprises the following steps:
(1) Screening of test reservoirs
The index of the test oil reservoir screening comprises the content of the biological limestone of the test oil reservoir, and the oil reservoir with the biological limestone content being more than 15% is screened.
(2) Screening of test reservoir acid producing functional microorganisms
The screening of acid-producing functional microorganisms is based on the pH value, caCO 3 powder mass loss and corrosion rate.
(3) Determination of test reservoir in situ injection Process
The on-site injection process of the test oil reservoir comprises the injection amount, injection mode and well closing culture time of acid-producing functional microorganisms and nutrient solution thereof.
(4) Site test and effect evaluation
Injecting acid-producing functional microorganisms and nutrient solution into a test oil reservoir, injecting water normally for 5-7d after injection, closing the well for culture, recovering water injection, and evaluating the effect after the test is finished.
Preferably, the criteria for the test reservoir screening further include: the permeability of the oil deposit is less than or equal to 1000 multiplied by 10 -3μm2, and the temperature of the oil deposit is less than or equal to 90 ℃; the viscosity of crude oil is less than or equal to 10000 Pa.s; the mineralization degree of stratum water is less than or equal to 50000mg/L.
In the present invention, preferably, the screening of the acid-producing functional microorganism comprises the following specific steps:
150mL of the produced liquid of the test oil reservoir is put into an anaerobic bottle with the volume of 200mL, the acid-producing functional microorganisms and nutrient solution thereof are inoculated in the anaerobic bottle in a sterile operation mode, then the anaerobic bottle is placed into an incubator for culturing for 10-30d, the temperature of the incubator is set to be the temperature of the test oil reservoir, after the experiment is finished, the pH value and the mass loss and corrosion rate of CaCO 3 powder are measured by the culture liquid, and the acid-producing functional microorganisms are screened out according to the pH value, the CaCO 3 powder mass loss and the corrosion rate.
Preferably, the CaCO 3 powder mass loss and erosion rate are determined by the following specific methods: accurately weighing CaCO 3 powder m g, putting into a sealed reaction tube filled with 30mL of culture solution supernatant, reacting in an oil bath for 24-48h at the reaction temperature of a test oil reservoir, and weighing a Buchner funnel and filter paper before suction filtration to obtain m 1; after the reaction, the residue which is not eroded is dried to constant weight in an oven at 100 ℃, the mass m 2 is obtained after cooling, and the mass loss and erosion rate eta, eta= (m+m 1-m2)/mx100% of CaCO 3 powder are calculated.
Preferably, the acid-producing functional microorganism is one or more of lactic acid bacteria, acetobacter, clostridium acetobutylicum and streptococcus thermophilus, more preferably streptococcus thermophilus or clostridium acetobutylicum.
Preferably, the lactic acid bacteria is one of the genus lactobacillus and the genus bifidobacterium.
In the invention, preferably, the nutrient solution formula of the lactobacillus and the acetobacter is composed of 0.1-0.5% of sodium thiosulfate, 0.1-0.3% of sodium nitrate, 0.1-0.3% of sodium dihydrogen phosphate, 0.05-0.2% of sodium bicarbonate, 0.01-0.1% of magnesium chloride hexahydrate and 0.01-0.03% of ferrous sulfate heptahydrate. More preferably, the sodium thiosulfate is 0.2-0.3% by mass, the sodium nitrate is 0.1-0.2% by mass, the sodium dihydrogen phosphate is 0.2-0.3% by mass, the sodium bicarbonate is 0.1-0.15% by mass, the magnesium chloride hexahydrate is 0.02-0.05% by mass, and the ferrous sulfate heptahydrate is 0.01-0.02% by mass.
Preferably, the nutrient solution formula of the clostridium acetobutylicum comprises 0.1-1.0% of beef mass concentration, 0.1-1.5% of peptone mass concentration and 0.1-1.0% of sodium chloride mass concentration. More preferably, the beef extract has a mass concentration of 0.3-0.5%, peptone has a mass concentration of 0.5-1.0%, and sodium chloride has a mass concentration of 0.2-0.5%.
In the invention, preferably, the nutrient solution formula of streptococcus thermophilus comprises 0.5-3% of soybean oil by mass, 0.1-0.8% of sodium nitrate by mass, 0.1-0.5% of dipotassium hydrogen phosphate by mass, 0.1-0.5% of potassium dihydrogen phosphate by mass, 0.05-0.2% of sodium chloride by mass and 0.05-0.3% of yeast powder by mass. More preferably, the mass concentration of soybean oil is 1.0-1.5%, the mass concentration of sodium nitrate is 0.2-0.5%, the mass concentration of dipotassium hydrogen phosphate is 0.2-0.4%, the mass concentration of potassium dihydrogen phosphate is 0.3-0.5%, the mass concentration of sodium chloride is 0.1-0.15%, and the mass concentration of yeast powder is 0.1-0.2%.
Preferably, the method for determining the injection amount of the acidogenic functional microorganism and the nutrient solution thereof specifically comprises the following steps:
adopting a natural rock core of a test oil reservoir, vacuumizing the rock core, saturating stratum water of the test oil reservoir, and measuring the pore volume PV of the rock core; dehydrated and degassed crude oil of a saturated test oil reservoir, aging a core for 7-10d, and calculating saturated oil quantity of the core; the core is subjected to primary water flooding until the water content of the produced liquid is consistent with the water content of the test oil reservoir, and the primary water flooding recovery ratio is calculated; injecting different amounts of acid-producing functional microorganisms into the core, and culturing for 10-30d; and (3) secondary water flooding, wherein the water flooding is carried out until the water content of the produced liquid is 100%, the core inlet pressure is monitored in the whole water flooding process, and the acid-producing functional microorganisms and the nutrient solution injection quantity are determined according to the recovery ratio increasing value and the core inlet pressure reducing amplitude.
In the present invention, preferably, the acid-producing functional microorganism and the nutrient solution thereof are injected from a water injection well of the test reservoir by using a high-pressure pump truck slug.
Preferably, the shut-in culture time of the acid-producing functional microorganism and the nutrient solution thereof is 5-25d.
In the invention, preferably, the well closing culture time of the acidogenic functional microorganism lactobacillus and the nutrient solution thereof is 5-10d, the well closing culture time of the acidogenic functional microorganism bacillus aceticus and the nutrient solution thereof is 10-15d, the well closing culture time of the acidogenic functional microorganism clostridium acetobutylicum and the nutrient solution thereof is 15-20d, and the well closing culture time of the acidogenic functional microorganism streptococcus thermophilus and the nutrient solution thereof is 20-25d.
Preferably, the indexes of the effect evaluation include: the water injection pressure reduction amplitude, the water injection quantity increase amplitude, the input-output ratio and the validity period.
The invention will be described in further detail below with reference to specific examples and with reference to the data. It should be understood that these examples are intended to illustrate the invention and are not intended to limit the scope of the invention in any way.
Example 1:
A test block A profile of a winning oil field: the oil reservoir temperature is 80 ℃, the biological limestone content is 20%, the permeability is 453 multiplied by 10 -3μm2, the mineralization degree of stratum water is 11000mg/L, the viscosity of crude oil is 210 mPa.s, the geological reserve of a test well group is 1.2 multiplied by 10 5 t, the pore volume is 3.42 multiplied by 10 5m3, the comprehensive water content is 89.5%, and the method for improving the yield of the block comprises the following specific steps:
(1) Screening of test reservoirs
The biological limestone content of the test block A is 20%, the oil reservoir temperature is 80 ℃, the oil reservoir permeability is 453× -3μm2, the crude oil viscosity is 210 mPa.s, and the formation water mineralization degree is 11000mg/L. The test block A meets the reservoir screening criteria of the present invention and can be used to practice the present invention.
(2) Screening of test reservoir acid producing functional microorganisms
Screening of acid-producing functional microorganisms, wherein the specific method comprises the following steps: 150mL of the output liquid of the test block A is put into an anaerobic bottle with the volume of 200mL, the acid-producing functional microorganisms and nutrient solution thereof are inoculated in a sterile operation mode, the anaerobic bottle is placed in an incubator with the temperature of 80 ℃ for 20d for culture, the temperature change in the anaerobic bottle is observed in the experimental process, and the pH value of the system is measured after the experiment is finished; and (3) accurately weighing 10g of CaCO 3 powder in a 30mL sealed reaction tube of supernatant, putting the powder into the sealed reaction tube, reacting for 24 hours at 80 ℃ in an oil bath at the oil storage temperature, and weighing a Buchner funnel and filter paper before suction filtration. And (3) carrying out suction filtration again after the reaction, drying the residues which are not eroded to constant weight in an oven at 100 ℃, and weighing the mass after cooling. The mass loss and erosion rate of the fermentation broth on CaCO 3 powder were calculated. And screening out acid-producing functional microorganisms with the greatest pH change and the highest loss and corrosion rate to CaCO 3 powder. The test results are shown in Table 1.
TABLE 1 pH and loss and erosion Rate for CaCO 3 for different acidogenic functional microorganisms
| Acid producing functional microorganism | Original pH value | Post-experiment pH | Loss and erosion Rate% |
| Lactic acid bacteria (Lactobacillus) | 6.8 | 2.5 | 85.3 |
| Lactic acid bacteria (Bifidobacterium) | 6.8 | 3.0 | 81.7 |
| Acetobacter | 6.8 | 2.0 | 90.5 |
| Clostridium acetobutylicum | 6.8 | 3.3 | 78.3 |
| Streptococcus thermophilus | 6.8 | 4.1 | 61.1 |
Wherein the nutrient solution formula of lactobacillus (Lactobacillus) comprises sodium thiosulfate 0.1%, sodium nitrate 0.2%, sodium dihydrogen phosphate 0.1%, sodium bicarbonate 0.15%, magnesium chloride hexahydrate 0.02% and ferrous sulfate heptahydrate 0.02%.
The nutrient solution formula of lactobacillus (Bifidobacterium) comprises sodium thiosulfate 0.1%, sodium nitrate 0.3%, sodium dihydrogen phosphate 0.2%, sodium bicarbonate 0.05%, magnesium chloride hexahydrate 0.01% and ferrous sulfate heptahydrate 0.01%.
The nutrient solution formula of the acetobacter is 0.1% of sodium thiosulfate, 0.1% of sodium nitrate, 0.3% of sodium dihydrogen phosphate, 0.05% of sodium bicarbonate, 0.1% of magnesium chloride hexahydrate and 0.03% of ferrous sulfate heptahydrate.
The nutrient solution formula of clostridium acetobutylicum comprises 0.1% of beef extract, 0.1% of peptone and 0.1% of sodium chloride.
The nutrient solution formula of streptococcus thermophilus comprises 2.0% of soybean oil, 0.1% of sodium nitrate, 0.3% of dipotassium hydrogen phosphate, 0.1% of potassium dihydrogen phosphate, 0.12% of sodium chloride and 0.05% of yeast powder.
As can be seen from table 1: the pH of the acetobacter is lowest, the pH reduction value is maximally 4.8, and the loss and corrosion rate of CaCO 3 are maximally 90.5%, so that the screened acidogenic functional microorganism is acetobacter, and the formula of the nutrient solution is sodium thiosulfate 0.1%, sodium nitrate 0.1%, sodium dihydrogen phosphate 0.3%, sodium bicarbonate 0.05%, magnesium chloride hexahydrate 0.1% and ferrous sulfate heptahydrate 0.03%.
(3) Determination of test reservoir in situ injection Process
The method for determining the on-site injection amount of the acetobacter and the nutrient solution thereof comprises the following steps:
adopting a natural rock core of the test block A, vacuumizing the rock core, saturating stratum water of the test block A, and measuring the pore volume PV of the rock core; dehydrated and degassed crude oil of a saturated test oil reservoir, aging a core for 7d, and calculating saturated oil quantity of the core; the core is subjected to primary water flooding until the water content of the produced liquid reaches 89.5%, and the primary water flooding recovery ratio is calculated; injecting the screened 0.1PV acetobacter and nutrient solution thereof, wherein the volume ratio of the acetobacter and the nutrient solution thereof is 1:9, and hermetically culturing for 10d at 80 ℃; a second water flooding is carried out until the water content of the produced fluid is 100%, wherein the water flooding of the core of the control group is continued; and calculating the secondary water flooding of the core to improve the recovery rate value. The pressure at the injection end was measured during the water flooding process and is shown in table 2. And determining the optimal on-site injection amount of the acetobacter and the nutrient solution thereof according to the increased recovery rate value.
TABLE 2 pressure drop values and enhanced recovery values for cores at different injection rates
As can be seen from table 2: with the increase of the injection amount of the acetobacter fermentation broth and the nutrient solution thereof, the recovery rate value and the pressure drop value of the core are increased, but when the injection amount is more than 0.25PV, the recovery rate value and the pressure drop of the core are not obvious, so that the determined optimal injection amount of the acetobacter and the nutrient solution thereof on site is 0.25PV.
The acetobacter and nutrient solution thereof are injected from a water injection well of a test oil reservoir by utilizing a high-pressure locomotive segment plug.
The closing culture time of the acetobacter and the nutrient solution thereof is 10d.
(4) Site test and effect evaluation
And (3) injecting 8.55X10 4m3 acetobacter and nutrient solution thereof into a test oil reservoir, normally injecting water for 5 days after injection, closing a well, culturing for 10 days, recovering water injection, and evaluating the effect after the test is finished.
The nutrient solution formula of the acetobacter is 0.1% of sodium thiosulfate, 0.1% of sodium nitrate, 0.3% of sodium dihydrogen phosphate, 0.05% of sodium bicarbonate, 0.1% of magnesium chloride hexahydrate and 0.03% of ferrous sulfate heptahydrate.
And after the field test is finished, evaluating the field test effect, wherein the evaluation indexes comprise water injection pressure reduction amplitude, water injection quantity increase amplitude, input-output ratio and effective period.
After the on-site implementation, the water injection pressure of the block A is reduced by 40.5%, the water capacity of Shan Jingzhu is increased by 65.3%, the accumulated oil increment is 0.21 multiplied by 10 5 t, the recovery ratio is improved by 17.2%, the input-output ratio is 1:8.5, the effective period is 6.5 years, and the on-site test effect is good.
Example 2:
Test block B profile for a winning field: the oil reservoir temperature is 83 ℃, the content of biological limestone is 22%, the thickness of an oil layer is 5.5m, the permeability is 390 multiplied by 10 -3μm2, the mineralization degree of stratum water is 13000mg/L, the viscosity of crude oil is 331 mPa.s, the comprehensive water content is 95.0%, the geological reserve of a test well group is 1.8X10 4 t, the pore volume is 3.35X10 5m3, and the method for improving the yield of the block comprises the following specific steps of:
(1) Screening of test reservoirs
The biological limestone content of the test block B is 22%, the oil reservoir temperature is 83 ℃, the oil reservoir permeability is 390 multiplied by 10 -3μm2, the crude oil viscosity is 331 mPa.s, and the formation water mineralization degree is 13000mg/L. The test block B meets the reservoir screening criteria of the present invention and may be used in the practice of the present invention.
(2) Screening of test reservoir acid producing functional microorganisms
Screening of acid-producing functional microorganisms, wherein the specific method comprises the following steps: 150mL of the output liquid of the test block B is filled into an anaerobic bottle with the volume of 200mL, the acid-producing functional microorganisms and nutrient solution thereof are inoculated in a sterile operation mode, the table 3 is shown, then the anaerobic bottle is placed into an incubator with the temperature of 83 ℃ for culture for 25d, and the pH of the system is measured after the experiment is finished; and (3) accurately weighing 10g of CaCO3 powder in a 30mL sealed reaction tube of supernatant, putting the CaCO3 powder in the sealed reaction tube, reacting for 24 hours at the oil storage temperature in an oil bath, and weighing a Buchner funnel and filter paper before suction filtration. And (3) carrying out suction filtration again after the reaction, drying the residues which are not eroded to constant weight in an oven at 100 ℃, and weighing the mass after cooling. And calculating the mass loss and corrosion rate of the fermentation liquor on CaCO3 powder. Screening out the microbes with acid-producing function with the greatest PH temperature change and the highest corrosion rate to CaCO3 powder. The test results are shown in Table 3.
TABLE 3 pH and loss and erosion Rate for CaCO 3 for various acid-forming functional microorganisms
| Acid producing functional microorganism | Original pH value | Post-experiment pH | Loss and erosion Rate% |
| Lactic acid bacteria (Lactobacillus) | 6.8 | 4.0 | 68.5 |
| Lactic acid bacteria (Bifidobacterium) | 6.5 | 3.5 | 75.3 |
| Acetobacter | 6.5 | 2.8 | 85.6 |
| Clostridium acetobutylicum | 6.5 | 4.2 | 62.3 |
| Streptococcus thermophilus | 6.5 | 2.3 | 92.5 |
Wherein the nutrient solution formula of lactobacillus (Lactobacillus) comprises sodium thiosulfate 0.5%, sodium nitrate 0.3%, sodium dihydrogen phosphate 0.15%, sodium bicarbonate 0.12%, magnesium chloride hexahydrate 0.05%, and ferrous sulfate heptahydrate 0.03%.
The nutrient solution formula of lactobacillus (Bifidobacterium) comprises sodium thiosulfate 0.5%, sodium nitrate 0.25%, sodium dihydrogen phosphate 0.10%, sodium bicarbonate 0.08%, magnesium chloride hexahydrate 0.02% and ferrous sulfate heptahydrate 0.01%.
The nutrient solution formula of the acetobacter is 0.2% of sodium thiosulfate, 0.15% of sodium nitrate, 0.25% of sodium dihydrogen phosphate, 0.08% of sodium bicarbonate, 0.02% of magnesium chloride hexahydrate and 0.03% of ferrous sulfate heptahydrate.
The nutrient solution formula of the clostridium acetobutylicum comprises 0.3% of beef extract, 1.5% of peptone and 1.0% of sodium chloride.
The nutrient solution formula of streptococcus thermophilus comprises 0.5% of soybean oil, 0.5% of sodium nitrate, 0.4% of dipotassium hydrogen phosphate, 0.4% of potassium dihydrogen phosphate, 0.15% of sodium chloride and 0.1% of yeast powder.
As can be seen from table 3: the pH of the streptococcus thermophilus is lowest, the maximum pH reduction value reaches 4.2, and the maximum loss and corrosion rate of CaCO 3 reach 92.5%, so that the screened acidogenic functional microorganism is streptococcus thermophilus, and the nutrient solution formula of the acidogenic functional microorganism is soybean oil 0.5%, sodium nitrate 0.5%, dipotassium hydrogen phosphate 0.4%, potassium dihydrogen phosphate 0.4%, sodium chloride 0.15% and yeast powder 0.1%.
(3) Determination of test reservoir in situ injection Process
The method for determining the site injection quantity of streptococcus thermophilus and the nutrient solution thereof comprises the following steps:
Adopting a natural rock core of the test block B, vacuumizing the rock core, saturating stratum water of the block B, and measuring the pore volume PV of the rock core; dehydrated and degassed crude oil of a saturated test oil reservoir, aging the core for 8 days, and calculating the saturated oil quantity of the core; the core is subjected to primary water flooding until the water content of the produced liquid is 95.0%, and the primary water flooding recovery ratio is calculated; injecting the screened 0.15PV streptococcus thermophilus and the nutrient solution thereof, wherein the volume ratio of the streptococcus thermophilus to the nutrient solution thereof is 1:9, and hermetically culturing for 20d at 83 ℃; a second water flooding is carried out until the water content of the produced fluid is 100%, wherein the water flooding of the core of the control group is continued; and calculating the secondary water flooding of the core to improve the recovery rate value. The pressure at the injection end was measured during the water flooding process and is shown in table 4. And determining the optimal injection quantity of the streptococcus thermophilus and the nutrient solution on site according to the increased recovery rate value.
TABLE 4 pressure drop values and enhanced recovery values for cores at different injection rates
As can be seen from table 4: with the increase of the injection amount of the streptococcus thermophilus fermentation liquid and the nutrient solution thereof, the improved recovery rate value and the wellhead pressure drop value of the core are increased, but when the injection amount is more than 0.2PV, the improved recovery rate value and the pressure drop value of the core are not obvious, so that the determined optimal injection amount of the streptococcus thermophilus and the nutrient solution thereof on site is 0.2PV.
The streptococcus thermophilus and the nutrient solution thereof are injected from a water injection well of a test oil reservoir by utilizing a high-pressure locomotive segment plug.
The closing culture time of streptococcus thermophilus and nutrient solution thereof is 22d.
(4) Site test and effect evaluation
And (3) injecting 0.67 multiplied by 10 5m3 streptococcus thermophilus and nutrient solution thereof into the test oil reservoir B, normally injecting water for 7d after the injection is completed, closing the well and culturing for 22d, finally recovering the water injection, and performing effect evaluation after the test is completed.
The streptococcus thermophilus nutrient solution comprises 0.5% of soybean oil, 0.5% of sodium nitrate, 0.4% of dipotassium hydrogen phosphate, 0.4% of potassium dihydrogen phosphate, 0.15% of sodium chloride and 0.1% of yeast powder.
And after the field test is finished, evaluating the field test effect, wherein the evaluation indexes comprise water injection pressure reduction amplitude, water injection quantity increase amplitude, input-output ratio and effective period.
After the on-site implementation, the water injection pressure of the block B is reduced by 43.5%, the water capacity of Shan Jingzhu is increased by 62.5%, the accumulated oil increment is 0.33 multiplied by 10 4 t, the recovery ratio is improved by 18.6%, the input-output ratio is 1:9.8, the effective period is 7.5 years, and the on-site test effect is good.
Example 3:
Test block C profile for a winning field: the oil reservoir temperature is 65 ℃, the biological limestone content is 25.3%, the permeability is 510 multiplied by 10 -3μm2, the mineralization degree of stratum water is 18000mg/L, the viscosity of crude oil is 650 mPa.s, the comprehensive water content is 78%, the geological reserve of a test well group is 1.6X10 4 t, the pore volume is 2.2X10 5m3, and the method for improving the yield of the block comprises the following specific steps:
(1) Screening of test reservoirs
The biological limestone content of the test block C is 25.3%, the oil reservoir temperature is 65 ℃, the oil reservoir permeability is 510 multiplied by 10 -3μm2, the crude oil viscosity is 650 mPa.s, and the formation water mineralization degree is 18000mg/L. The test block C meets the reservoir screening criteria of the present invention and can be used to practice the present invention.
(2) Screening of test reservoir acid producing functional microorganisms
Screening of acid-producing functional microorganisms, wherein the specific method comprises the following steps: 150mL of the output liquid of the test block C is taken and put into an anaerobic bottle with the volume of 200mL, the acid-producing functional microorganisms and nutrient solution thereof are inoculated in the aseptic operation, the table 5 is shown, then the anaerobic bottle is placed into a 65 ℃ incubator for 30d of culture, and the system pH is measured after the experiment is finished; and (3) accurately weighing 10g of CaCO 3 powder in a 30mL sealed reaction tube of supernatant, putting the powder into the sealed reaction tube, reacting for 48 hours at the oil storage temperature in an oil bath, and weighing a Buchner funnel and filter paper before suction filtration. And (3) carrying out suction filtration again after the reaction, drying the residues which are not eroded to constant weight in an oven at 100 ℃, and weighing the mass after cooling. The mass loss and erosion rate of the fermentation broth on CaCO 3 powder were calculated. And screening out acid-producing functional microorganisms with the greatest pH temperature change and the highest corrosion rate to CaCO 3 powder. The test results are shown in Table 5.
TABLE 5 pH and loss and erosion Rate for CaCO 3 for various acid-forming functional microorganisms
| Acid producing functional microorganism | Original pH value | Post-experiment pH | Loss and erosion Rate% |
| Lactic acid bacteria (Lactobacillus) | 6.7 | 4.0 | 75.2 |
| Lactic acid bacteria (Bifidobacterium) | 6.7 | 3.8 | 80.3 |
| Acetobacter | 6.7 | 3.1 | 85.6 |
| Clostridium acetobutylicum | 6.7 | 2.0 | 96.8 |
| Streptococcus thermophilus | 6.7 | 2.5 | 91.2 |
Wherein the nutrient solution formula of lactobacillus (Lactobacillus) comprises sodium thiosulfate 0.3%, sodium nitrate 0.25%, sodium dihydrogen phosphate 0.25%, sodium bicarbonate 0.05%, magnesium chloride hexahydrate 0.01%, and ferrous sulfate heptahydrate 0.01%.
The nutrient solution formula of lactobacillus (Bifidobacterium) comprises sodium thiosulfate 0.2%, sodium nitrate 0.2%, sodium dihydrogen phosphate 0.25%, sodium bicarbonate 0.15%, magnesium chloride hexahydrate 0.05% and ferrous sulfate heptahydrate 0.02%.
The nutrient solution formula of the acetobacter is 0.3% of sodium thiosulfate, 0.20% of sodium nitrate, 0.20% of sodium dihydrogen phosphate, 0.10% of sodium bicarbonate, 0.05% of magnesium chloride hexahydrate and 0.02% of ferrous sulfate heptahydrate.
The nutrient solution formula of clostridium acetobutylicum comprises 0.5% of beef extract, 1.0% of peptone and 0.5% of sodium chloride.
The nutrient solution formula of streptococcus thermophilus comprises 2.5% of soybean oil, 0.8% of sodium nitrate, 0.5% of dipotassium hydrogen phosphate, 0.2% of potassium dihydrogen phosphate, 0.2% of sodium chloride and 0.15% of yeast powder.
As can be seen from table 5: the pH amplitude reduction of clostridium acetobutylicum reaches 4.7 at maximum, and the loss and corrosion rate of CaCO 3 reach 96.8 at maximum, so that the screened acidogenic functional microorganisms are clostridium acetobutylicum, and the nutrient solution formula comprises 0.5% of beef extract, 1.0% of peptone and 0.5% of sodium chloride.
(3) Determination of test reservoir in situ injection Process
The method for determining the on-site injection amount of clostridium acetobutylicum and nutrient solution thereof specifically comprises the following steps:
Taking a natural core of the block C; vacuumizing the rock core, saturating stratum water, and measuring the pore volume PV of the rock core; aging the saturated crude oil and the core for 10 days, and calculating the original oil saturation; a primary water flooding is carried out, the water flooding reaches 78.0% of the water content of the produced liquid, and the primary water flooding recovery ratio is calculated; injecting the selected clostridium acetobutylicum and nutrient solution thereof into the culture medium, wherein the volume ratio of the clostridium acetobutylicum to the nutrient solution thereof is 1:9, and hermetically culturing the culture medium for 15d at 65 ℃; a second water flooding is carried out until the water content of the produced fluid is 100%, wherein the water flooding of the core of the control group is continued; and calculating the secondary water flooding of the core to improve the recovery rate value. The pressure at the injection end was measured during the water flooding process and is shown in table 6. And determining the optimal injection quantity of clostridium acetobutylicum and nutrient solution on site according to the increased recovery rate value.
TABLE 6 pressure drop values and enhanced recovery values for cores at different injection rates
As can be seen from table 6: with the increase of the injection amount of the clostridium acetobutylicum fermentation liquid and the nutrient solution thereof, the improved recovery rate value and the pressure drop value of the core are increased, but when the injection amount is more than 0.25PV, the improved recovery rate value and the pressure drop value of the core are not obvious, so that the determined optimal injection amount of the clostridium acetobutylicum and the nutrient solution thereof on site is 0.25PV.
The clostridium acetobutylicum and nutrient solution thereof are injected from a water injection well of a test oil reservoir by utilizing a high-pressure truck segment plug.
The shut-in culture time of clostridium acetobutylicum and nutrient solution thereof is 18d.
(4) Site test and effect evaluation
And (3) injecting the clostridium acetobutylicum with the concentration of 0.55 multiplied by 10 5m3 and nutrient solution into the test oil reservoir C, normally injecting water for 5 days after the injection is completed, closing the well and culturing for 18 days, and finally recovering the water injection, and performing effect evaluation after the test is completed.
The nutrient solution formula of clostridium acetobutylicum comprises 0.5% of beef extract, 1.0% of peptone and 0.5% of sodium chloride.
And after the field test is finished, evaluating the field test effect, wherein the evaluation indexes comprise water injection pressure reduction amplitude, water injection quantity increase amplitude, input-output ratio and effective period.
After the on-site implementation, the water injection pressure of the block C is reduced by 50.3%, the water capacity of Shan Jingzhu is increased by 75.6%, the accumulated oil increment is 0.34 multiplied by 10 4 t, the recovery ratio is improved by 21.3%, the input-output ratio is 1:12.5, the effective period is 8.2 years, and the on-site test effect is good.
Example 4:
Test block D profile for a winning field: the oil reservoir temperature is 55 ℃, the biological limestone content is 18.2%, the permeability is 560 multiplied by 10 -3μm2, the stratum water mineralization degree is 11000mg/L, the crude oil viscosity is 2000 mPa.s, the comprehensive water content is 90%, the geological reserve of a test well group is 5.0 multiplied by 10 4 t, the pore volume is 7.5 multiplied by 10 5m3, and the method for improving the yield of the block comprises the following specific steps of:
(1) Screening of test reservoirs
The biological limestone content of the test block D is 18.2%, the oil reservoir temperature is 55 ℃, the oil reservoir permeability is 560 multiplied by 10 -3μm2, the crude oil viscosity is 2000 mPa.s, and the formation water mineralization degree is 11000mg/L. The test block D meets the reservoir screening criteria of the present invention and may be used in the practice of the present invention.
(2) Screening of test reservoir acid producing functional microorganisms
Screening of acid-producing functional microorganisms, wherein the specific method comprises the following steps: 150mL of the output liquid of the test block D is put into an anaerobic bottle with the volume of 200mL, the acid-producing functional microorganisms and nutrient solution thereof are inoculated in a sterile operation mode, the table 7 is shown, then the anaerobic bottle is placed into a 55 ℃ incubator for culture for 25D, and the pH of the system is measured after the experiment is finished; and (3) accurately weighing 10g of CaCO 3 powder in a sealed reaction tube with 30mL of supernatant, putting the powder into the sealed reaction tube, reacting for 30h at the oil storage temperature in an oil bath, and weighing a Buchner funnel and filter paper before suction filtration. And (3) carrying out suction filtration again after the reaction, drying the residues which are not eroded to constant weight in an oven at 100 ℃, and weighing the mass after cooling. The mass loss and erosion rate of the fermentation broth on CaCO 3 powder were calculated. Screening out acidogenic microorganisms with the greatest pH temperature change and the highest corrosion rate to CaCO3 powder. The test results are shown in Table 7.
TABLE 7 pH and loss and erosion Rate for CaCO 3 for various acid-forming functional microorganisms
| Acid producing functional microorganism | Original pH value | Post-experiment pH | Loss and erosion Rate% |
| Lactic acid bacteria (Lactobacillus) | 7.1 | 2.3 | 92.3 |
| Lactic acid bacteria (Bifidobacterium) | 7.1 | 2.5 | 91.0 |
| Acetobacter | 7.1 | 4.2 | 71.3 |
| Clostridium acetobutylicum | 7.1 | 3.5 | 78.5 |
| Streptococcus thermophilus | 7.1 | 3.0 | 85.6 |
Wherein the nutrient solution formula of lactobacillus (Lactobacillus) comprises sodium thiosulfate 0.4%, sodium nitrate 0.15%, sodium dihydrogen phosphate 0.3%, sodium bicarbonate 0.2%, magnesium chloride hexahydrate 0.1% and ferrous sulfate heptahydrate 0.02%.
The nutrient solution formula of lactobacillus (Bifidobacterium) comprises sodium thiosulfate 0.4%, sodium nitrate 0.10%, sodium dihydrogen phosphate 0.15%, sodium bicarbonate 0.10%, magnesium chloride hexahydrate 0.08% and ferrous sulfate heptahydrate 0.02%.
The nutrient solution formula of the acetobacter is 0.4% of sodium thiosulfate, 0.25% of sodium nitrate, 0.15% of sodium dihydrogen phosphate, 0.15% of sodium bicarbonate, 0.08% of magnesium chloride hexahydrate and 0.01% of ferrous sulfate heptahydrate.
The nutrient solution formula of clostridium acetobutylicum comprises 0.8% of beef extract, 1.2% of peptone and 0.8% of sodium chloride.
The nutrient solution formula of streptococcus thermophilus comprises 3.0% of soybean oil, 0.3% of sodium nitrate, 0.1% of dipotassium hydrogen phosphate, 0.5% of potassium dihydrogen phosphate, 0.05% of sodium chloride and 0.20% of yeast powder.
As can be seen from table 7: the pH of lactobacillus (lactobacillus) is reduced by up to 4.8, and the loss and corrosion rate of CaCO 3 are up to 92.3%, so that the screened acid-producing functional microorganism is lactobacillus (lactobacillus), and the nutrient solution comprises 0.4% of sodium thiosulfate, 0.15% of sodium nitrate, 0.3% of sodium dihydrogen phosphate, 0.2% of sodium bicarbonate, 0.1% of magnesium chloride hexahydrate and 0.02% of ferrous sulfate heptahydrate.
(3) Determination of test reservoir in situ injection Process
The method for determining the site injection amount of lactobacillus (lactobacillus) and nutrient solution thereof comprises the following steps:
Taking a natural core of the block D; vacuumizing the rock core, saturating stratum water, and measuring the pore volume PV of the rock core; aging the saturated crude oil and the core for 9 days, and calculating the original oil saturation; a primary water flooding is carried out until the water content of the produced liquid is 90.0%, and the primary water flooding recovery ratio is calculated; injecting the selected 0.25PV lactobacillus (Lactobacillus) and its nutrient solution, and hermetically culturing at test reservoir temperature for 25d; a second water flooding is carried out until the water content of the produced fluid is 100%, wherein the water flooding of the core of the control group is continued; and calculating the secondary water flooding of the core to improve the recovery rate value. The pressure at the injection end was measured during the water flooding process and is shown in table 8. And determining the optimal injection amount of lactobacillus and its nutrient solution in site according to the increased recovery rate.
Table 8 pressure drop values and enhanced recovery values for cores at different injection rates
As can be seen from table 8: with the increase of the injection amount of the lactobacillus and the nutrient solution thereof, the improved recovery rate value and the pressure drop value of the core are increased, but when the injection amount is more than 0.25PV, the improved recovery rate value and the pressure drop of the core are not obvious, so that the determined optimal injection amount of the lactobacillus and the nutrient solution thereof on site is 0.25PV.
The lactobacillus and its nutrient solution are injected from the water injection well of the test oil reservoir by using the high-pressure truck segment plug.
The shut-in culture time of lactobacillus (Lactobacillus) and its nutrient solution is 6d.
(4) Site test and effect evaluation
1.88X10 5m3 lactobacillus and nutrient solution thereof are injected into a test oil reservoir D, normal water injection is carried out for 6D after the injection is completed, then well closing culture is carried out for 6D, finally water injection is restored, and effect evaluation is carried out after the test is completed.
The formula of the lactobacillus nutrient solution comprises 0.4% of sodium thiosulfate, 0.15% of sodium nitrate, 0.3% of sodium dihydrogen phosphate, 0.2% of sodium bicarbonate, 0.1% of magnesium chloride hexahydrate and 0.02% of ferrous sulfate heptahydrate.
And after the field test is finished, evaluating the field test effect, wherein the evaluation indexes comprise water injection pressure reduction amplitude, water injection quantity increase amplitude, input-output ratio and effective period.
After the on-site implementation, the water injection pressure of the block D is reduced by 46.0%, the water capacity of Shan Jingzhu is increased by 61.3%, the accumulated oil increment is 0.785 multiplied by 10 multiplied by 4 t, the recovery ratio is improved by 15.7%, the input-output ratio is 1:8.7, the effective period is 6.5 years, and the on-site test effect is good.
Example 5:
test block E profile for a field: the oil reservoir temperature is 82 ℃, the biological limestone content is 26.7%, the permeability is 390 multiplied by 10 -3μm2, the mineralization degree of stratum water is 7120mg/L, the viscosity of crude oil is 5120 mPa.s, the geological reserve of a test well group is 4.2 multiplied by 10 4 t, the pore volume is 6.8 multiplied by 10 5m3, the comprehensive water content is 88%, and the method for improving the yield of the block comprises the following specific steps:
(1) Screening of test reservoirs
The biological limestone content of the test block E is 26%, the oil reservoir temperature is 82 ℃, the oil reservoir permeability is 390 multiplied by 10 -3μm2, the crude oil viscosity is 5120 mPa.s, and the formation water mineralization degree is 7120mg/L. The test block E meets the reservoir screening criteria of the present invention and can be used to practice the present invention.
(2) Screening of test reservoir acid producing functional microorganisms
Screening of acid-producing functional microorganisms, wherein the specific method comprises the following steps: 150mL of the output liquid of the test block E is put into an anaerobic bottle with the volume of 200mL, the acid-producing functional microorganisms and nutrient solution thereof are inoculated in a sterile operation mode, the anaerobic bottle is placed in an incubator with the temperature of 82 ℃ for 20d, the temperature change in the anaerobic bottle is observed in the experimental process, and the pH value of the system is measured after the experimental process is finished; taking supernatant 30ML in a sealed reaction tube, accurately weighing 10g of CaCO 3 powder, putting the powder into the sealed reaction tube, reacting for 40 hours at the oil storage temperature in an oil bath, and weighing a Buchner funnel and filter paper before suction filtration. And (3) carrying out suction filtration again after the reaction, drying the residues which are not eroded to constant weight in an oven at 100 ℃, and weighing the mass after cooling. The mass loss and erosion rate of the fermentation broth on CaCO 3 powder were calculated. And screening out acid-producing functional microorganisms with the greatest pH temperature change and the highest corrosion rate to CaCO 3 powder. The test results are shown in Table 9.
TABLE 9 pH and loss and erosion Rate for CaCO 3 for various acid-forming functional microorganisms
| Acid producing functional microorganism | Original pH value | Post-experiment pH | Loss and erosion Rate% |
| Lactic acid bacteria (Lactobacillus) | 7.0 | 3.1 | 81.3 |
| Lactic acid bacteria (Bifidobacterium) | 7.0 | 3.5 | 75.6 |
| Acetobacter | 7.0 | 2.5 | 94.2 |
| Clostridium acetobutylicum | 7.0 | 3.0 | 85.6 |
| Streptococcus thermophilus | 7.0 | 4.0 | 72.7 |
Wherein the nutrient solution formula of lactobacillus (Lactobacillus) comprises sodium thiosulfate 0.2%, sodium nitrate 0.1%, sodium dihydrogen phosphate 0.2%, sodium bicarbonate 0.1%, magnesium chloride hexahydrate 0.08%, and ferrous sulfate heptahydrate 0.01%.
The nutrient solution formula of lactobacillus (Bifidobacterium) comprises sodium thiosulfate 0.3%, sodium nitrate 0.15%, sodium dihydrogen phosphate 0.3%, sodium bicarbonate 0.20%, magnesium chloride hexahydrate 0.1% and ferrous sulfate heptahydrate 0.03%.
The nutrient solution formula of the acetobacter is 0.5% of sodium thiosulfate, 0.3% of sodium nitrate, 0.1% of sodium dihydrogen phosphate, 0.2% of sodium bicarbonate, 0.01% of magnesium chloride hexahydrate and 0.01% of ferrous sulfate heptahydrate.
The nutrient solution formula of the clostridium acetobutylicum is 1.0 percent of beef extract, 0.5 percent of peptone and 0.2 percent of sodium chloride.
The nutrient solution formula of streptococcus thermophilus comprises 1.0% of soybean oil, 0.2% of sodium nitrate, 0.2% of dipotassium hydrogen phosphate, 0.3% of potassium dihydrogen phosphate, 0.1% of sodium chloride and 0.3% of yeast powder.
As can be seen from table 9: the pH value of the acetobacter is reduced to 4.5 at most, and the loss and corrosion rate of CaCO 3 are up to 94.2%, so that the screened acidogenic functional microorganism is acetobacter, and the nutrient solution formula of the acetobacter comprises 0.5% of sodium thiosulfate, 0.3% of sodium nitrate, 0.1% of sodium dihydrogen phosphate, 0.2% of sodium bicarbonate, 0.01% of magnesium chloride hexahydrate and 0.01% of ferrous sulfate heptahydrate.
(3) Determination of test reservoir in situ injection Process
The method for determining the on-site injection amount of the acetobacter and the nutrient solution thereof comprises the following steps:
adopting a natural core of a test oil reservoir E, vacuumizing the core, saturating stratum water of the test oil reservoir, and measuring the pore volume PV of the core; dehydrated and degassed crude oil of a saturated test oil reservoir, aging the core for 8 days, and calculating the saturated oil quantity of the core; performing primary water flooding on the core until the water content of the produced liquid is 88%, and calculating the primary water flooding recovery ratio; injecting the screened 0.3PV acetobacter and nutrient solution thereof, wherein the volume ratio of the acetobacter and the nutrient solution thereof is 1:9, and hermetically culturing for 30d at 82 ℃; a second water flooding is carried out until the water content of the produced fluid is 100%, wherein the water flooding of the core of the control group is continued; and calculating the secondary water flooding of the core to improve the recovery rate value. The pressure at the injection end was measured during the water flooding process and is shown in table 10. And determining the optimal on-site injection amount of the acetobacter and the nutrient solution thereof according to the increased recovery rate value.
Table 10 pressure drop values and enhanced recovery values for cores at different injection rates
As can be seen from table 10: with the increase of the injection amount of the acetobacter fermentation broth and the nutrient solution thereof, the recovery rate increasing value and the wellhead pressure reducing value of the core are increased, but when the injection amount is more than 0.2PV, the recovery rate increasing value and the pressure reducing value of the core are not obvious, so that the determined optimal injection amount of the acetobacter and the nutrient solution thereof on site is 0.2PV.
The acetobacter and nutrient solution thereof are injected from a water injection well of a test oil reservoir by utilizing a high-pressure locomotive segment plug.
The closing culture time of the acetobacter and the nutrient solution thereof is 15d.
(4) Site test and effect evaluation
And (3) injecting the bacillus aceti with the concentration of 1.36 multiplied by 10 5m3 and nutrient solution thereof into the test oil reservoir E, injecting water normally for 7d after the injection, closing the well for 15d of culture, recovering the water injection, and evaluating the effect after the test is finished.
The formula of the bacillus aceti nutrient solution comprises 0.5% of sodium thiosulfate, 0.3% of sodium nitrate, 0.1% of sodium dihydrogen phosphate, 0.2% of sodium bicarbonate, 0.01% of magnesium chloride hexahydrate and 0.01% of ferrous sulfate heptahydrate.
And after the field test is finished, evaluating the field test effect, wherein the evaluation indexes comprise water injection pressure reduction amplitude, water injection quantity increase amplitude, input-output ratio and effective period.
After the on-site implementation, the water injection pressure of the block E is reduced by 47.3%, the water capacity of Shan Jingzhu is increased by 70.2%, the accumulated oil increment is 0.71 multiplied by 10 4 t, the recovery ratio is improved by 16.8%, the input-output ratio is 1:9.5, the effective period is 8 years, and the on-site test effect is good.
Claims (13)
1. A method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms is characterized by comprising the following steps:
(1) Screening of test reservoirs
The indexes of the test oil reservoir screening comprise the content of the biological limestone of the test oil reservoir, and the oil reservoir with the biological limestone content being more than 15% is screened;
(2) Screening of test reservoir acid producing functional microorganisms
The screening basis of the acid-producing functional microorganisms is the pH value, caCO 3 powder quality loss and corrosion rate;
(3) Determination of test reservoir in situ injection Process
The on-site injection process of the test oil reservoir comprises the injection quantity, injection mode and well closing culture time of acid-producing functional microorganisms and nutrient solution thereof;
(4) Site test and effect evaluation
Injecting acid-producing functional microorganisms and nutrient solution into a test oil reservoir, injecting water normally for 5-7d after injection, closing a well for culture, recovering water injection, and evaluating the effect after the test is finished;
the criteria for the test reservoir screening further include: the permeability of the oil deposit is less than or equal to 1000 multiplied by 10 -3μm2, and the temperature of the oil deposit is less than or equal to 90 ℃; the viscosity of crude oil is less than or equal to 10000 Pa.s; the mineralization degree of stratum water is less than or equal to 50000mg/L;
The screening of the acid-producing functional microorganisms comprises the following specific steps: 150mL of output liquid of a test oil reservoir is put into an anaerobic bottle with the volume of 200mL, acid-producing functional microorganisms and nutrient solution thereof are inoculated in the anaerobic bottle in a sterile operation mode, then the anaerobic bottle is placed into an incubator for culturing for 10-30d, the temperature of the incubator is set to be the temperature of the test oil reservoir, after the experiment is finished, the pH value and the mass loss and corrosion rate of CaCO 3 powder are measured by the culture liquid, and the acid-producing functional microorganisms are screened out according to the pH value, the CaCO 3 powder mass loss and the corrosion rate;
The method for determining the injection amount of the acidogenic functional microorganism and the nutrient solution thereof comprises the following steps: adopting a natural rock core of a test oil reservoir, vacuumizing the rock core, saturating stratum water of the test oil reservoir, and measuring the pore volume PV of the rock core; dehydrated and degassed crude oil of a saturated test oil reservoir, aging a core for 7-10d, and calculating saturated oil quantity of the core; the core is subjected to primary water flooding until the water content of the produced liquid is consistent with the water content of the test oil reservoir, and the primary water flooding recovery ratio is calculated; injecting different amounts of acid-producing functional microorganisms and nutrient solution into the core, and culturing for 10-30d; monitoring the inlet pressure of the core in the whole process of water flooding until the water content of the produced liquid is 100%, and determining the injection quantity of acid-producing functional microorganisms and nutrient solution according to the recovery ratio increasing value and the core inlet pressure reducing amplitude;
the acid-producing functional microorganisms and nutrient solution are injected from a water injection well of a test oil reservoir by utilizing a high-pressure locomotive sectional plug;
the acid-producing functional microorganism is one or more of lactobacillus, acetobacter, clostridium acetobutylicum and streptococcus thermophilus.
2. The method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms according to claim 1, wherein the determination of the mass loss and the erosion rate of CaCO 3 powder is as follows: accurately weighing CaCO 3 powder m g, putting into a sealed reaction tube filled with 30mL of culture solution supernatant, reacting in an oil bath for 24-48h at the reaction temperature of a test oil reservoir, and weighing a Buchner funnel and filter paper before suction filtration to obtain m 1; after the reaction, the residue which is not eroded is dried to constant weight in an oven at 100 ℃, the mass m 2 is obtained after cooling, and the mass loss and erosion rate eta, eta= (m+m 1-m2)/mx100% of CaCO 3 powder are calculated.
3. The method for improving the development effect of a biological limestone oil reservoir by using acid-producing microorganisms according to claim 1, wherein the acid-producing functional microorganisms are streptococcus thermophilus or clostridium acetobutylicum.
4. The method for improving the development effect of a biological limestone oil reservoir by using acid-producing microorganisms according to claim 1, wherein the lactic acid bacteria is one of lactobacillus and bifidobacterium.
5. The method for improving the development effect of the biological limestone oil reservoir by utilizing acidogenic microorganisms according to claim 1, wherein the nutrient solution formula of the lactic acid bacteria and the acetobacter is characterized in that the nutrient solution formula comprises 0.1-0.5% of sodium thiosulfate, 0.1-0.3% of sodium nitrate, 0.1-0.3% of sodium dihydrogen phosphate, 0.05-0.2% of sodium bicarbonate, 0.01-0.1% of magnesium chloride hexahydrate and 0.01-0.03% of ferrous sulfate heptahydrate.
6. The method for improving the development effect of a biological limestone oil reservoir by utilizing acidogenic microorganisms according to claim 1, wherein the nutrient solution formula of clostridium acetobutylicum is beef mass concentration extract 0.1-1.0%, peptone mass concentration 0.1-1.5% and sodium chloride mass concentration 0.1-1.0%.
7. The method for improving the development effect of a biological limestone oil reservoir by utilizing acidogenic microorganisms according to claim 1, wherein the nutrient solution formula of the streptococcus thermophilus is characterized by comprising 0.5-3% of soybean oil by mass, 0.1-0.8% of sodium nitrate by mass, 0.1-0.5% of dipotassium hydrogen phosphate by mass, 0.1-0.5% of potassium dihydrogen phosphate by mass, 0.05-0.2% of sodium chloride by mass and 0.05-0.3% of yeast powder by mass.
8. The method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms according to claim 1, wherein the shut-in culture time of the acid-producing functional microorganisms and nutrient solution thereof is 5-25d.
9. The method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms according to claim 1, wherein the shut-in culture time of the acid-producing functional microorganisms lactobacillus and nutrient solution thereof is 5-10d.
10. The method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms according to claim 1, wherein the shut-in culture time of the acid-producing functional microorganisms of acetobacter and nutrient solution thereof is 10-15d.
11. The method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms according to claim 1, wherein the shut-in culture time of the acid-producing functional microorganisms clostridium acetobutylicum and nutrient solution thereof is 15-20d.
12. The method for improving the development effect of a biological limestone oil reservoir by utilizing acid-producing microorganisms according to claim 1, wherein the shut-in culture time of the acid-producing functional microorganisms streptococcus thermophilus and nutrient solution thereof is 20-25d.
13. The method for improving the development effect of a biological limestone oil reservoir by using acid-producing microorganisms according to claim 1, wherein the index of the effect evaluation comprises: the water injection pressure reduction amplitude, the water injection quantity increase amplitude, the input-output ratio and the validity period.
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