CN110939418A - Endogenous microorganism single-well huff and puff oil production method - Google Patents
Endogenous microorganism single-well huff and puff oil production method Download PDFInfo
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- 244000005700 microbiome Species 0.000 title claims abstract description 17
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 16
- 239000012190 activator Substances 0.000 claims abstract description 52
- 239000003129 oil well Substances 0.000 claims abstract description 38
- 238000012216 screening Methods 0.000 claims abstract description 31
- 238000000034 method Methods 0.000 claims abstract description 27
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 22
- 230000000694 effects Effects 0.000 claims abstract description 19
- 238000002347 injection Methods 0.000 claims abstract description 16
- 239000007924 injection Substances 0.000 claims abstract description 16
- 238000011156 evaluation Methods 0.000 claims abstract description 15
- 239000003921 oil Substances 0.000 claims description 73
- VWDWKYIASSYTQR-UHFFFAOYSA-N sodium nitrate Chemical compound [Na+].[O-][N+]([O-])=O VWDWKYIASSYTQR-UHFFFAOYSA-N 0.000 claims description 24
- 239000008398 formation water Substances 0.000 claims description 21
- 239000001888 Peptone Substances 0.000 claims description 16
- 108010080698 Peptones Proteins 0.000 claims description 16
- 235000019319 peptone Nutrition 0.000 claims description 16
- 229910000402 monopotassium phosphate Inorganic materials 0.000 claims description 15
- 235000019796 monopotassium phosphate Nutrition 0.000 claims description 15
- WQZGKKKJIJFFOK-GASJEMHNSA-N Glucose Natural products OC[C@H]1OC(O)[C@H](O)[C@@H](O)[C@@H]1O WQZGKKKJIJFFOK-GASJEMHNSA-N 0.000 claims description 14
- 239000008103 glucose Substances 0.000 claims description 14
- 235000013379 molasses Nutrition 0.000 claims description 14
- ZPWVASYFFYYZEW-UHFFFAOYSA-L dipotassium hydrogen phosphate Chemical group [K+].[K+].OP([O-])([O-])=O ZPWVASYFFYYZEW-UHFFFAOYSA-L 0.000 claims description 13
- 238000004945 emulsification Methods 0.000 claims description 13
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 12
- 239000010779 crude oil Substances 0.000 claims description 12
- PJNZPQUBCPKICU-UHFFFAOYSA-N phosphoric acid;potassium Chemical compound [K].OP(O)(O)=O PJNZPQUBCPKICU-UHFFFAOYSA-N 0.000 claims description 12
- 235000010344 sodium nitrate Nutrition 0.000 claims description 12
- 239000004317 sodium nitrate Substances 0.000 claims description 12
- 230000033558 biomineral tissue development Effects 0.000 claims description 8
- 230000035699 permeability Effects 0.000 claims description 8
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 claims description 6
- OAICVXFJPJFONN-UHFFFAOYSA-N Phosphorus Chemical compound [P] OAICVXFJPJFONN-UHFFFAOYSA-N 0.000 claims description 6
- 229910052799 carbon Inorganic materials 0.000 claims description 6
- 229910052757 nitrogen Inorganic materials 0.000 claims description 6
- 229910052698 phosphorus Inorganic materials 0.000 claims description 6
- 239000011574 phosphorus Substances 0.000 claims description 6
- 230000001580 bacterial effect Effects 0.000 claims description 5
- 238000012258 culturing Methods 0.000 claims description 5
- 230000008569 process Effects 0.000 claims description 5
- 125000002791 glucosyl group Chemical group C1([C@H](O)[C@@H](O)[C@H](O)[C@H](O1)CO)* 0.000 claims description 2
- 238000011084 recovery Methods 0.000 claims 1
- 230000003213 activating effect Effects 0.000 abstract description 13
- 239000003795 chemical substances by application Substances 0.000 abstract description 12
- 230000000813 microbial effect Effects 0.000 abstract description 4
- 238000001514 detection method Methods 0.000 description 6
- 238000009472 formulation Methods 0.000 description 6
- 239000000203 mixture Substances 0.000 description 6
- LWIHDJKSTIGBAC-UHFFFAOYSA-K potassium phosphate Substances [K+].[K+].[K+].[O-]P([O-])([O-])=O LWIHDJKSTIGBAC-UHFFFAOYSA-K 0.000 description 6
- 229910000396 dipotassium phosphate Inorganic materials 0.000 description 3
- 235000019797 dipotassium phosphate Nutrition 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- GNSKLFRGEWLPPA-UHFFFAOYSA-M potassium dihydrogen phosphate Chemical compound [K+].OP(O)([O-])=O GNSKLFRGEWLPPA-UHFFFAOYSA-M 0.000 description 3
- 238000000926 separation method Methods 0.000 description 3
- 230000000704 physical effect Effects 0.000 description 2
- 241000894006 Bacteria Species 0.000 description 1
- 230000032683 aging Effects 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000002207 metabolite Substances 0.000 description 1
- 235000015097 nutrients Nutrition 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 230000000638 stimulation Effects 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
Classifications
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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
- 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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- 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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- General Life Sciences & Earth Sciences (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- Geochemistry & Mineralogy (AREA)
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Abstract
The invention belongs to the technical field of microbial oil production, and particularly relates to a method for single-well huff and puff oil production by endogenous microbes, which comprises the following steps: screening a test oil well; screening an activating agent; determining the injection amount of the activating agent; determining the well shut-in time; and (4) field test and evaluation of test effect. The invention has strong pertinence, and the endogenous activators are respectively screened according to the temperatures of different oil layers, so that the screened activator formula can effectively activate endogenous microorganisms in different oil layers of a test oil well; meanwhile, the method has the characteristics of simplicity, strong operability and good field test effect, the effective period of the oil well is more than 24 months, the water content is reduced by more than 10 percent, the average daily oil increase of a single well is more than 10t, and the input-output ratio is more than 1: 8. Therefore, the invention can be widely applied to the field test for improving the oil well yield.
Description
Technical Field
The invention relates to a microbial oil production method, in particular to a method for producing oil by huff and puff of an endogenous microbial single well.
Background
The single well throughput of the endogenous microorganism is to inject an activating agent for screening into a production well (oil well), the endogenous microorganism in an oil reservoir is activated by the injected activating agent, and the near-well area and a shaft of the oil well are treated by utilizing the functions of the endogenous microorganism and a metabolite thereof, so that the aims of improving the physical property of crude oil, reducing the flow resistance of the crude oil and improving the yield of the oil well are fulfilled. The single well huff and puff of the endogenous microorganism has the characteristics of less ground investment, simple operation, quick response and the like, and particularly plays roles in improving the physical property of crude oil, reducing the flow resistance of the crude oil and improving the production aging of the crude oil for oil well shafts and near well zones.
In the prior art, publication No. CN103291267B, entitled "a method for increasing oil well production using reservoir indigenous microorganisms", discloses a method for increasing oil well production using reservoir indigenous microorganisms, comprising the steps of: screening a test oil well; screening an activating agent; determining the injection amount of the activating agent; determining the well shut-in time; and (4) field test. The disadvantages of this method are: the screening of the activating agent in the step of screening the activating agent is carried out under the condition of oil reservoir temperature (average temperature of oil layers), and the actual oil reservoir consists of a plurality of oil layers, and the temperature of each layer of oil layer is different, so that the activating agent obtained by screening by the method can not effectively activate the endogenous microorganisms of each oil layer in the oil reservoir, thereby influencing the effect of single-well throughput of the endogenous microorganisms to a certain extent.
Disclosure of Invention
The present invention is to overcome the above-mentioned shortcomings of the prior art and to provide a method for single well stimulation oil production by endogenous microorganisms, which can greatly increase the single well yield by effectively activating the endogenous microbial community in each oil layer of a test oil well. The method has the advantages of simplicity, strong pertinence and operability and good field test effect.
The invention discloses a method for single-well huff and puff oil production by endogenous microorganisms, which is characterized by comprising the following steps of:
(1) screening of test wells
The screening of the test oil well needs to meet the following conditions: the oil deposit temperature of the test oil well is less than 80 ℃, the formation water mineralization is less than 100000mg/L, and the permeability is more than 200 multiplied by 10-3μm2The viscosity of the crude oil is less than 5000mPa.s, the water content is less than 96%, and the layer position of the oil layer is more than 2.
(2) Screening for activators
The specific steps of screening for activators are as follows:
① determining the reservoir temperature of each reservoir of the test well;
② separating oil from water to obtain formation water;
③ taking the above stratum water, injecting activator with the same number of stratum parts as that of the tested oil well, and culturing at different oil layer temperatures of the tested oil well for 15-30 d;
④, after the culture time is over, detecting the total bacterial concentration and emulsification index of each activated formation water;
⑤ the strains screened by the method are all greater than 1.0 multiplied by 108The activator formula has a single/ml and an emulsification index of more than 80 percent.
(3) Determination of the amount of activator injected
The injection amount of the activator is related to the total oil layer thickness of the test oil well, and the injection amount is 20-30m per meter of the oil layer thickness3。
(4) Shut-in time determination
The shut-in time of the test oil well is 15-30 d.
(5) On-site test and evaluation of test Effect
And (3) carrying out field test on the test oil well according to the process determined in the steps, and evaluating the effect of the field test after the field test is finished, wherein the evaluation indexes comprise the average daily oil increment of the single well, the effective period and the input-output ratio.
The activator consists of a carbon source, a nitrogen source and a phosphorus source, wherein the carbon source is glucose or molasses, the nitrogen source is peptone or sodium nitrate, and the phosphorus source is dipotassium hydrogen phosphate or potassium dihydrogen phosphate.
The mass concentration of the carbon source is 3-5%, the mass concentration of the nitrogen source is 0.2-0.5%, and the mass concentration of the phosphorus source is 0.05-0.1%.
Compared with the prior art, the invention has the following advantages and beneficial effects:
(1) endogenous microorganisms existing in the oil well are activated, and other exogenous microorganisms are not required to be added manually, so that the cost of field test is saved;
(2) the invention has strong pertinence, and the endogenous activators are respectively screened according to the temperatures of different oil layers, so that the screened activator formula can effectively activate endogenous microorganisms in different oil layers of a test oil well;
(3) the injected endogenous activator is a nutrient substance, so that the stratum cannot be damaged and the environment cannot be polluted;
(4) the method has the characteristics of simplicity, strong operability and good field test effect, the effective period of the oil well is more than 24 months, the water content is reduced by more than 10 percent, the average daily oil increase of a single well is more than 10t, and the input-output ratio is more than 1: 8.
Detailed description of the invention
The technical solution of the present invention is further described below with reference to examples.
Example 1:
test well F2Overview: reservoir temperature of 62 ℃, formation water mineralization degree of 8562mg/L and permeability of 750 multiplied by 10-3μm2Original, originalOil viscosity 2536mPa.s, water content 95.5%, 3 oil layers for the test well, F2 1、F2 2、F2 3The oil layer temperature is respectively 55 ℃, 60 ℃ and 70 ℃, the total thickness of the oil layer is 8.2m, and the daily oil production of the oil well before the test is 1.2 t. The specific steps for implementing the invention in the well are as follows:
(1) screening of test wells
Test well F2The oil reservoir temperature is 62 ℃, the formation water mineralization is 8562mg/L, and the permeability is 750 multiplied by 10-3μm2The crude oil viscosity is 2536mPa.s, the water content is 95.5%, the oil layer level is 3 layers, the screening standard of the invention is met, and the invention can be implemented.
(2) Screening for activators
The specific steps of screening for activators are as follows:
① determining test well F2Each oil layer F2 1、F2 2、F2 3The oil layer temperature is 55 ℃, 60 ℃ and 70 ℃;
② test well F2The produced liquid is subjected to oil-water separation to obtain a test oil well F2The formation water of (a);
③ taking 3 parts of the above stratum water, injecting activator, and culturing at 55 deg.C, 60 deg.C, 70 deg.C for 15 d;
④ after the culture time is over, detecting the total bacterial concentration and emulsification index of each activated formation water, and the detection results are shown in Table 1;
⑤ the strains screened by the method are all greater than 1.0 multiplied by 108The activator formula has a single/ml and an emulsification index of more than 80 percent.
TABLE 1 test well F2The detection result of the activated formation water under different oil layer temperatures
Note: formula 1: 3% of glucose, 0.3% of peptone and 0.05% of dipotassium hydrogen phosphate; and (2) formula: 4% of glucose, 0.3% of sodium nitrate and 0.1% of potassium dihydrogen phosphate; and (3) formula: 5% of glucose, 0.2% of peptone and 0.08% of dipotassium hydrogen phosphate; and (4) formula: 3% of molasses, 0.3% of sodium nitrate and 0.1% of dipotassium phosphate; and (5) formula: molasses 4%, peptone 0.5%, potassium dihydrogen phosphate 0.05%; and (6) formula: 5% of molasses, 0.3% of sodium nitrate and 0.06% of monopotassium phosphate.
As can be seen from Table 1, the concentrations of activator formulation 5 (molasses 4%, peptone 0.5%, potassium dihydrogen phosphate 0.05%) at 55 deg.C, 60 deg.C, and 70 deg.C were 2.0 × 108Each/ml, 5.0X 1083.0X 10 pieces/ml8Each/ml is more than 1.0X 108ml/min; the emulsification indexes are 82%, 85% and 83% respectively, and are all larger than 80%, which meet the screening index, so the activator formula 5 is the final screened activator formula.
(3) Determination of the amount of activator injected
The injection amount of the activating agent is related to the total oil layer thickness of the test oil well, and the injection amount is 20m per meter of the oil layer thickness3The injection amount of the activator is 164m3。
(4) Shut-in time determination
Test well F2The shut-in time of (2) is 15 d.
(5) On-site test and evaluation of test Effect
Test well F2The process was determined according to the above procedure (activator formulation: molasses 4%, peptone 0.5%, potassium dihydrogen phosphate 0.05%, activator injection: 164m3And closing the well for 15d) to carry out a field test, and evaluating the effect of the field test after the field test is finished, wherein the evaluation indexes comprise the average daily oil increment of a single well, the effective period and the input-output ratio.
Evaluation results of the field test: test well F2The validity period is 30 months; the water content is reduced from 95.5 percent before the test to 83.2 percent, and is reduced by 12.3 percent; the average daily oil increase of a single well is 11.5t, and the input-output ratio is 1: 9.5. The field test effect is good.
Example 2:
test well F5Overview: the oil deposit temperature is 65 ℃, the formation water mineralization is 12536mg/L, and the permeability is 900 multiplied by 10-3μm2Crude oil viscosity 3250mPa.s, water content95.0%, the test well had 3 oil layers, F respectively5 1、F5 2、F5 3The oil layer temperature is 58 ℃, 63 ℃ and 72 ℃, the total thickness of the oil layer is 12.5m, and the daily oil production of the oil well before the test is 2.1 t. The invention is implemented in the well, and the specific steps are as follows:
(1) screening of test wells
Test well F5The oil deposit temperature is 65 ℃, the formation water mineralization is 12536mg/L, and the permeability is 900 multiplied by 10-3μm2The viscosity of crude oil is 3250mPa.s, the water content is 95.0%, the layer level of an oil layer is 3 layers, the screening standard of the invention is met, and the invention can be implemented.
(2) Screening for activators
The specific steps of screening for activators are as follows:
① determining test well F5Each oil layer F5 1、F5 2、F5 3The oil layer temperature is 58 ℃, 63 ℃ and 72 ℃;
② test well F5The produced liquid is subjected to oil-water separation to obtain a test oil well F5The formation water of (a);
③ taking 3 parts of the above stratum water, injecting activator, and culturing at 58 deg.C, 63 deg.C, and 72 deg.C for 20 d;
④ after the culture time is over, detecting the total bacterial concentration and emulsification index of each activated formation water, and the detection results are shown in Table 2;
⑤ the strains screened by the method are all greater than 1.0 multiplied by 108The activator formula has a single/ml and an emulsification index of more than 80 percent.
TABLE 2 test well F5The detection result of the activated formation water under different oil layer temperatures
Note: formula 1: 3% of glucose, 0.3% of peptone and 0.05% of dipotassium hydrogen phosphate; and (2) formula: 4% of glucose, 0.3% of sodium nitrate and 0.1% of potassium dihydrogen phosphate; and (3) formula: 5% of glucose, 0.2% of peptone and 0.08% of dipotassium hydrogen phosphate; and (4) formula: 3% of molasses, 0.3% of sodium nitrate and 0.1% of dipotassium phosphate; and (5) formula: molasses 4%, peptone 0.5%, potassium dihydrogen phosphate 0.05%; and (6) formula: 5% of molasses, 0.3% of sodium nitrate and 0.06% of monopotassium phosphate.
As can be seen from Table 2, the concentrations of the activator formulation 3 (glucose 5%, peptone 0.2%, dipotassium hydrogenphosphate 0.08%) at 58 deg.C, 63 deg.C, and 72 deg.C were 2.0X 1083.0X 10 pieces/ml8Each/ml, 5.0X 108Each/ml is more than 1.0X 108ml/min; the emulsification indexes are 83%, 85% and 88%, and are all more than 80%, which meet the screening index, so the activator formula 3 is the final screened activator formula.
(3) Determination of the amount of activator injected
The injection amount of the activating agent is related to the total oil layer thickness of the test oil well, and 25m is injected into each meter of the oil layer thickness3The injection amount of the activator is 312.5m3。
(4) Shut-in time determination
Test well F5The shut-in time of (2) is 20 d.
(5) On-site test and evaluation of test Effect
Test well F5The process was determined according to the above procedure (activator formulation: glucose 5%, peptone 0.2%, dipotassium hydrogenphosphate 0.08%, activator injection 312.5m3And closing the well for 20d) to carry out a field test, and evaluating the effect of the field test after the field test is finished, wherein the evaluation indexes comprise the average daily oil increment of a single well, the effective period and the input-output ratio.
Evaluation results of the field test: test well F5The validity period is 32 months; the water content is reduced to 82.8 percent from 95.0 percent before the test, and is reduced by 12.2 percent; the average daily oil increase of a single well is 12.1t, and the input-output ratio is 1: 10.3. The field test effect is good.
Example 3:
test well F12Overview: oil deposit temperature is 70 ℃, formation water mineralization degree is 4562mg/L, and permeability is 1100 multiplied by 10-3μm2Crude oil viscosity of 1856mPa.s, water content of 94.8%,the test well had 3 oil layers, F respectively12 1、F12 2、F12 3The oil layer temperature is 67 ℃, 72 ℃ and 78 ℃, the total thickness of the oil layer is 10.0m, and the daily oil production of the oil well before the test is 1.8 t. The specific steps for implementing the invention in the well are as follows:
(1) screening of test wells
Test well F12Oil deposit temperature of 70 ℃, formation water mineralization of 4562mg/L and permeability of 1100 multiplied by 10-3μm2The crude oil viscosity is 1856mPa.s, the water content is 94.8%, the oil layer level is 3 layers, which accords with the screening standard of the invention, and the invention can be implemented.
(2) Screening for activators
The specific steps of screening for activators are as follows:
① determining test well F12Each oil layer F12 1、F12 2、F12 3The oil layer temperature is 67 ℃, 72 ℃ and 78 ℃ respectively;
② test well F12The produced liquid is subjected to oil-water separation to obtain a test oil well F12The formation water of (a);
③ taking 3 parts of the above stratum water, injecting activator, and culturing at 67 deg.C, 72 deg.C, 78 deg.C for 30 d;
④ after the culture time is over, detecting the total bacterial concentration and emulsification index of each activated formation water, and the detection results are shown in Table 3;
⑤ the concentration of the selected bacteria is more than 108The activator formula has a single/ml and an emulsification index of more than 80 percent.
TABLE 3 test well F12The detection result of the activated formation water under different oil layer temperatures
Note: formula 1: 3% of glucose, 0.3% of peptone and 0.05% of dipotassium hydrogen phosphate; and (2) formula: 4% of glucose, 0.3% of sodium nitrate and 0.1% of potassium dihydrogen phosphate; and (3) formula: 5% of glucose, 0.2% of peptone and 0.08% of dipotassium hydrogen phosphate; and (4) formula: 3% of molasses, 0.3% of sodium nitrate and 0.1% of dipotassium phosphate; and (5) formula: molasses 4%, peptone 0.5%, potassium dihydrogen phosphate 0.05%; and (6) formula: 5% of molasses, 0.3% of sodium nitrate and 0.06% of monopotassium phosphate.
As can be seen from Table 3, the concentrations of the activator formulation 2 (glucose 4%, sodium nitrate 0.3%, potassium dihydrogen phosphate 0.1%) at 67 deg.C, 72 deg.C, and 78 deg.C were 3.0X 1082.0X 10 pieces/ml8Each/ml, 5.0X 108Each/ml is more than 1.0X 108ml/min, the emulsification indexes are 85%, 82% and 87%, which are all more than 80%, and the screening indexes are met, so that the activator formula 5 is the final screened activator formula.
(3) Determination of the amount of activator injected
The injection amount of the activating agent is related to the total oil layer thickness of the test oil well, and 30m is injected into each meter of the oil layer thickness3The injection amount of the activator is 300m3。
(4) Shut-in time determination
Test well F12The shut-in time of (2) is 30 d.
(5) On-site test and evaluation of test Effect
Test well F12The process was determined according to the above procedure (activator formulation: molasses 4%, peptone 0.5%, potassium dihydrogen phosphate 0.05%, activator injection: 300m3And closing the well for 30d) to carry out a field test, and evaluating the effect of the field test after the field test is finished, wherein the evaluation indexes comprise the average daily oil increment of a single well, the effective period and the input-output ratio.
Evaluation results of the field test: test well F12The validity period is 35 months; the moisture content is reduced to 82.8 percent from 94.8 percent before the test, and is reduced by 12.0 percent; the average daily oil increase of a single well is 13.2t, and the input-output ratio is 1: 11.5. The field test effect is good.
Claims (5)
1. The method for single-well huff and puff oil recovery by using the endogenous microorganisms is characterized by comprising the following steps of:
(1) screening of test wells
The screening of the test oil well needs to meet the following conditions: the oil deposit temperature of the test oil well is less than 80 ℃, the formation water mineralization is less than 100000mg/L, and the permeability is more than 200 multiplied by 10-3μm2The viscosity of the crude oil is less than 5000mPa.s, the water content is less than 96%, and the layer level of an oil layer is more than 2;
(2) screening for activators
The specific steps of screening for activators are as follows:
① determining the reservoir temperature of each reservoir of the test well;
② separating oil from water to obtain formation water;
③ taking the above stratum water, injecting activator with the same number of stratum parts as that of the tested oil well, and culturing at different oil layer temperatures of the tested oil well for 15-30 d;
④, after the culture time is over, detecting the total bacterial concentration and emulsification index of each activated formation water;
⑤ the strains screened by the method are all greater than 1.0 multiplied by 108Activator formula with each ml and emulsification index more than 80%;
(3) determination of the amount of activator injected
The injection amount of the activator is related to the total oil layer thickness of the test oil well, and the injection amount is 20-30m per meter of the oil layer thickness3；
(4) Determination of shut-in time
The shut-in time of the test oil well is 15-30 d;
(5) on-site test and evaluation of test Effect
And (4) carrying out field test on the test oil well according to the process determined in the step, and carrying out field test effect evaluation after the field test is finished.
2. The method of claim 1, wherein the activator comprises a carbon source, a nitrogen source, and a phosphorus source.
3. The method of claim 2, wherein the carbon source is glucose or molasses, the nitrogen source is peptone or sodium nitrate, and the phosphorus source is dipotassium hydrogen phosphate or potassium dihydrogen phosphate.
4. The method of claim 1 or 2, wherein the mass concentration of the carbon source is 3-5%, the mass concentration of the nitrogen source is 0.2-0.5%, and the mass concentration of the phosphorus source is 0.05-0.1%.
5. The method of claim 1 or 2, wherein the indicators of field trial effect evaluation comprise average daily oil production per well, expiration date and input-output ratio.
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN114427404A (en) * | 2020-09-23 | 2022-05-03 | 中国石油化工股份有限公司 | Microbial huff-puff oil production method for strong-edge-bottom water heavy oil reservoir |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN103291267A (en) * | 2013-06-14 | 2013-09-11 | 中国石油化工股份有限公司 | Method for improving oil well yields by means of oil pool indigenous microorganisms |
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