CN110700804B - Method for adding antihypertensive and augmented injection medicament - Google Patents
Method for adding antihypertensive and augmented injection medicament Download PDFInfo
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- CN110700804B CN110700804B CN201910955697.0A CN201910955697A CN110700804B CN 110700804 B CN110700804 B CN 110700804B CN 201910955697 A CN201910955697 A CN 201910955697A CN 110700804 B CN110700804 B CN 110700804B
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- 238000002347 injection Methods 0.000 title claims abstract description 106
- 239000007924 injection Substances 0.000 title claims abstract description 106
- 239000003814 drug Substances 0.000 title claims abstract description 72
- 238000000034 method Methods 0.000 title claims abstract description 18
- 230000003276 anti-hypertensive effect Effects 0.000 title claims description 7
- 230000003190 augmentative effect Effects 0.000 title description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 114
- 239000003129 oil well Substances 0.000 claims abstract description 21
- 239000010410 layer Substances 0.000 claims abstract description 10
- 239000002356 single layer Substances 0.000 claims abstract description 4
- 239000003795 chemical substances by application Substances 0.000 claims description 33
- 239000004094 surface-active agent Substances 0.000 claims description 24
- 238000005260 corrosion Methods 0.000 claims description 21
- 230000007797 corrosion Effects 0.000 claims description 21
- 239000004927 clay Substances 0.000 claims description 20
- 241000894006 Bacteria Species 0.000 claims description 18
- 239000003112 inhibitor Substances 0.000 claims description 17
- 244000005700 microbiome Species 0.000 claims description 12
- 229920000642 polymer Polymers 0.000 claims description 12
- 239000003381 stabilizer Substances 0.000 claims description 12
- 230000020477 pH reduction Effects 0.000 claims description 11
- 239000002736 nonionic surfactant Substances 0.000 claims description 10
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 10
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 10
- 125000000020 sulfo group Chemical group O=S(=O)([*])O[H] 0.000 claims description 10
- 230000000694 effects Effects 0.000 claims description 9
- 239000002734 clay mineral Substances 0.000 claims description 8
- 238000005516 engineering process Methods 0.000 claims description 7
- 230000036772 blood pressure Effects 0.000 claims description 6
- GXCLVBGFBYZDAG-UHFFFAOYSA-N N-[2-(1H-indol-3-yl)ethyl]-N-methylprop-2-en-1-amine Chemical compound CN(CCC1=CNC2=C1C=CC=C2)CC=C GXCLVBGFBYZDAG-UHFFFAOYSA-N 0.000 claims description 4
- 230000002159 abnormal effect Effects 0.000 claims description 3
- 239000012528 membrane Substances 0.000 claims description 3
- 238000010606 normalization Methods 0.000 claims description 3
- 230000035945 sensitivity Effects 0.000 claims description 3
- 238000009424 underpinning Methods 0.000 claims description 3
- 229910052500 inorganic mineral Inorganic materials 0.000 claims description 2
- 239000011707 mineral Substances 0.000 claims description 2
- 239000008280 blood Substances 0.000 claims 1
- 210000004369 blood Anatomy 0.000 claims 1
- 230000002354 daily effect Effects 0.000 description 16
- 239000011148 porous material Substances 0.000 description 8
- -1 polysiloxane sulfosuccinate Polymers 0.000 description 6
- 238000010276 construction Methods 0.000 description 4
- 239000002245 particle Substances 0.000 description 4
- 239000002994 raw material Substances 0.000 description 4
- 229920003171 Poly (ethylene oxide) Polymers 0.000 description 3
- 241000589651 Zoogloea Species 0.000 description 3
- 239000002253 acid Substances 0.000 description 3
- 230000009286 beneficial effect Effects 0.000 description 3
- 229910052900 illite Inorganic materials 0.000 description 3
- VGIBGUSAECPPNB-UHFFFAOYSA-L nonaaluminum;magnesium;tripotassium;1,3-dioxido-2,4,5-trioxa-1,3-disilabicyclo[1.1.1]pentane;iron(2+);oxygen(2-);fluoride;hydroxide Chemical compound [OH-].[O-2].[O-2].[O-2].[O-2].[O-2].[F-].[Mg+2].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[Al+3].[K+].[K+].[K+].[Fe+2].O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2.O1[Si]2([O-])O[Si]1([O-])O2 VGIBGUSAECPPNB-UHFFFAOYSA-L 0.000 description 3
- 230000035699 permeability Effects 0.000 description 3
- 238000002360 preparation method Methods 0.000 description 3
- 230000005764 inhibitory process Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 230000000149 penetrating effect Effects 0.000 description 2
- 230000000644 propagated effect Effects 0.000 description 2
- 230000000844 anti-bacterial effect Effects 0.000 description 1
- 239000003899 bactericide agent Substances 0.000 description 1
- 239000009096 changqing Substances 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 230000003203 everyday effect Effects 0.000 description 1
- 230000007774 longterm Effects 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 229910052901 montmorillonite Inorganic materials 0.000 description 1
- 230000000630 rising effect Effects 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- 230000001502 supplementing effect Effects 0.000 description 1
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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
- E21B43/20—Displacing by water
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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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
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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
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
- C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/5086—Compositions based on water or polar solvents containing organic compounds macromolecular compounds obtained otherwise than by reactions only involving carbon-to-carbon unsaturated bonds
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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
- C09K8/54—Compositions for in situ inhibition of corrosion in boreholes or wells
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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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Abstract
The invention discloses a method for adding a pressure-reducing injection-increasing medicament, which comprises the first step of obtaining the minimum fracture pressure P of an oil well corresponding to the same layer position of a water injection welleAs threshold pressure; secondly, detecting the bottom hole pressure of the water injection well; and thirdly, when the water injection well is a multilayer underinjection well which is about to reach the threshold pressure and corresponds to an oil well with a high water content well, when the water injection well is about to reach the threshold pressure and corresponds to a single-layer underinjection well with a low water content well, when the water injection well is a non-underinjection well which is not yet reaching the threshold pressure and corresponds to an oil well with a low water content well, and when the oil pressure is low, the water injection well is a non-underinjection well which is previously injected with the pressure-reducing and injection-increasing medicament, and the theoretical medicine adding time t is calculated. By different dosing measures, the water injection pressure is reduced, and the injection pressure rise of a high-pressure underinjection well close to a well and a crack opening well close to the well is prevented.
Description
Technical Field
The invention belongs to the technical field of oilfield injection water development, and particularly relates to a method for adding a pressure-reducing and injection-increasing agent.
Background
Water injection is an effective means for supplementing stratum energy and ensuring long-term stable yield of an oil field, but part of low-permeability oil in the oil field in Changqing is hidden in the water injection development process, along with the extension of the water injection development, underinjection wells are increased year by year, the water injection pressure is increased year by year, meanwhile, more microcracks are gradually opened, the proportion of high-water-content wells and low-liquid-content wells in corresponding oil wells is increased year by year, the water drive effect range is poor, and the development contradiction is gradually exposed.
Therefore, to reduce the increase of the underinjection wells and prevent the ineffective fracture from opening, the injection pressure of the injection well must be reduced. At present, the method for reducing the water injection pressure of a water injection well at home and abroad is more, and mainly comprises acidification and injection increase and medicament addition. The scale inhibitor, the surfactant and the bactericide are mainly added in the adding of the medicaments, but the medicaments are all added into each well from a medicament tank of a water injection station every day, and the adding method has the characteristics of large dosage and lack of pertinence, and has poor effect on opening a well under high pressure near the well and a crack near the well.
Disclosure of Invention
The invention aims to provide a method for adding a pressure-reducing injection-increasing medicament, which determines the adding time of the pressure-reducing injection-increasing medicament according to well history and production data so as to reduce water injection pressure and prevent the injection pressure of a short injection well and a well opening near a well crack from rising.
The invention aims to realize the purpose through the following technical means, and the method for adding the pressure-reducing and injection-increasing medicament comprises the following steps:
firstly, acquiring the minimum fracture pressure P of the oil well corresponding to the same layer position of the water injection welleAs threshold pressure;
secondly, detecting the bottom hole pressure of the water injection well;
thirdly, when the water injection well is about to reach the threshold pressure and corresponds to a multilayer underinjection well with a high water-containing well in the oil well, a pressure-reducing and injection-increasing medicament is not injected, and a flow-dividing acidification technology is adopted to carry out acidification and injection-increasing on the side direction of the crack so as to plug the crack channel;
when the water injection well is about to reach the threshold pressure and a single-layer underclothing well with a low water-containing well is arranged corresponding to the oil well, a local pressurization device is installed on a well site, and then a pressure-reducing injection-increasing medicament is added into a medicament adding tank of the local pressurization device;
when the water injection well is an under-injection well which does not reach the threshold pressure and has a low water-containing well corresponding to the oil well and the oil pressure is low, a pressure-reducing and injection-increasing medicament is not injected, a local pressurization device is installed on a well site, and the oil pressure of the water injection well is increased to be 2-3 MPa lower than the threshold pressure;
when the water injection well is a non-underpinning injection well which has been injected with the blood pressure reducing and injection increasing medicament before, calculating theoretical medicine adding time t, installing a local pressurization device, and adding the blood pressure reducing and injection increasing medicament 3-4 months before the theoretical medicine adding time t;
in the third step, in the shunting acidification technology, shunting agents are used, and the shunting agents comprise 75-80% of bacteria for generating polymers by microorganisms in the malt, 3-5% of film-forming corrosion inhibitors, 3-5% of sulfo penetrants and 10-14% of alkylphenol polyoxyethylene ether nonionic surfactants by mass.
Further, the pressure-reducing injection-increasing medicament is one of a molecular membrane surfactant, a hetero-gemini surfactant or a nano oil-displacing agent.
Further, the pressure-reducing injection-increasing medicament is a mixture of a hetero-gemini surfactant and a long-acting clay stabilizer, when the content of the reservoir clay minerals is up to more than 20%, the reservoir clay is medium water-sensitive, and the volume ratio of the hetero-gemini surfactant to the long-acting clay stabilizer is 2: 1; when the content of the reservoir clay mineral is lower than 20%, the reservoir clay is free or weak in water sensitivity, and the volume ratio of the hetero-gemini surfactant to the long-acting clay stabilizer is 3: 1.
further, in the third step, when the water injection well is an insufficient injection well which does not reach the threshold pressure, and the water well is still insufficient injection after treatment, a pressure-reducing injection-increasing medicament is added, wherein the mass ratio of the medicament to the injected water is 0.5: 100-1: 100, and continuously adding the medicine for at least 3 months.
Further, in the third step, when the pressure-reducing injection-increasing agent is added, the mass ratio of the pressure-reducing injection-increasing agent to the injected water is 0.5: 100-1: 100, and continuously adding the medicine for at least 3 months.
Further, in the third step, the theoretical dosing time is calculated by collecting data of daily water injection amount and corresponding daily oil pressure after the last injection of the pressure-reducing and injection-increasing agent, drawing a fitting curve of the ratio of the daily water injection amount to the oil pressure and the time,
in the formula: t is theoretical dosing time;
qwthe daily water injection amount of the water injection well;
k is the slope of a fitting curve of the ratio of the water injection amount to the oil pressure and the time after the last measure of the pressure reduction and injection increase of the bet takes effect;
b is the ratio of the water injection amount to the oil pressure after the last measure of the pressure-reducing and injection-increasing agent is effective;
t0after the measures of the last-time bet pressure reduction and increasing injection of the medicament are taken, the measures take effect for a long time.
Further, after a fitting curve of the ratio of daily water injection amount to oil pressure and time is drawn, abnormal points are removed from the fitting curve, normalization processing and rarefaction processing are carried out, a new fitting curve is obtained, and the slope of the new fitting curve is used as k.
The invention has the beneficial effects that: 1. the bacteria which generate the polymer by the microorganisms can be propagated after entering the stratum and meeting water, the volume is increased, and the pore throat is blocked. Compared with the existing particle type flow dividing stage, the problem of blockage caused by mismatching of particles and pore throats is avoided. The flow divider can effectively block the pore throat by expanding the volume per se according to the size of the pore throat;
2. the corrosion inhibitor added into the invention can form a corrosion inhibition film on the surface of the pipe column, so that the corrosion of the corrosion inhibitor to the pipe column is reduced, the operation of the pipe column can be realized without moving the pipe column, the construction steps are effectively simplified, and the construction risk and cost are reduced;
3. the added penetrating agent and surface active agent improve the permeability, are more beneficial to the flow dividing agent to enter fine passages of the stratum and improve the swept area.
Drawings
FIG. 1 is a statistical graph of the ratio of water injection to oil pressure over time.
The present invention will be described in further detail with reference to the accompanying drawings and examples.
Detailed Description
[ example 1 ]
A method for adding a pressure-reducing and injection-increasing medicament comprises the following steps:
firstly, acquiring the minimum fracture pressure P of the oil well corresponding to the same layer position of the water injection welleAs threshold pressure; wherein the same layer position of the water injection well corresponds to the minimum fracture pressure P of the oil welleCan be obtained from the fracturing data of the oil well during normal pressure fracturing production.
Secondly, detecting the bottom hole pressure of the water injection well;
thirdly, when the water injection well is about to reach the threshold pressure and corresponds to a multilayer underinjection well with a high water-containing well in the oil well, a pressure-reducing and injection-increasing medicament is not injected, and a flow-dividing acidification technology is adopted to carry out acidification and injection-increasing on the side direction of the crack so as to plug the crack channel;
when the water injection well is about to reach the threshold pressure and a single-layer underclothing well with a low water-containing well is arranged corresponding to the oil well, a local pressurization device is installed on a well site, and then a pressure-reducing injection-increasing medicament is added into a medicament adding tank of the local pressurization device;
when the water injection well is an under-injection well which does not reach the threshold pressure and has a low water-containing well corresponding to the oil well and the oil pressure is low, a pressure-reducing and injection-increasing medicament is not injected, a local pressurization device is installed on a well site, and the oil pressure of the water injection well is increased to be 2-3 MPa lower than the threshold pressure;
when the water injection well is a non-underpinning injection well which has been injected with the blood pressure reducing and injection increasing medicament before, calculating theoretical medicine adding time t, installing a local pressurization device, and adding the blood pressure reducing and injection increasing medicament 3-4 months before the theoretical medicine adding time t;
in the third step, in the shunting acidification technology, shunting agents are used, and the shunting agents comprise 75-80% of bacteria for generating polymers by microorganisms in the malt, 3-5% of film-forming corrosion inhibitors, 3-5% of sulfo penetrants and 10-14% of alkylphenol polyoxyethylene ether nonionic surfactants by mass.
Wherein the low water content: the water content is 0-30%; medium water content: the water content is 30-60%; high water content: the water content is more than 60%.
[ example 2 ]
On the basis of the embodiment 1, the pressure-reducing injection-increasing medicament is one of a molecular membrane surfactant, a hetero-gemini surfactant or a nano oil-displacing agent.
The pressure-reducing injection-increasing medicament is prepared by mixing a heterogemini surfactant and a long-acting clay stabilizer, when the mineral content of the reservoir clay is up to more than 20%, the reservoir clay is medium water-sensitive, and the volume ratio of the heterogemini surfactant to the long-acting clay stabilizer is 2: 1; when the content of the reservoir clay mineral is lower than 20%, the reservoir clay is free or weak in water sensitivity, and the volume ratio of the hetero-gemini surfactant to the long-acting clay stabilizer is 3: 1.
for low permeability reservoirs, the medicament combining the heterogemini surfactant and the long-acting clay stabilizer is preferably selected.
When the clay mineral is more than 20 percent, wherein the illite and illite mixed layer in the clay mineral is more than 20 percent, the reservoir is medium water-sensitive, and the proportion of the heterogemini surfactant and the long-acting clay stabilizer in the pressure-reducing injection-increasing medicament is 2: 1; when the clay mineral is less than 20 percent, wherein the clay mineral has less content of illite and illite-montmorillonite mixed layers, the reservoir is free/weak water-sensitive, and the proportion of the heterogemini surfactant and the long-acting clay stabilizer in the pressure-reducing injection-increasing medicament is 3: 1.
in the third step, when the water injection well is an insufficient injection well which does not reach the threshold pressure and is treated, the water well is still insufficient injection, a pressure-reducing injection-increasing medicament is added, and the mass ratio of the medicament to the injected water is 0.5: 100 to 1: 100, and continuously adding the medicine for at least 3 months.
In the third step, in the shunting acidification technology, shunting agents are used, and the shunting agents comprise 75-80% of bacteria for generating polymers by microorganisms in the malt, 3-5% of film-forming corrosion inhibitors, 3-5% of sulfo penetrants and 10-14% of alkylphenol polyoxyethylene ether nonionic surfactants by mass.
In the third step, when the pressure-reducing injection-increasing medicament is added, the mass ratio of the pressure-reducing injection-increasing medicament to the injected water is 0.5: 100-1: 100, and continuously adding the medicine for at least 3 months.
The bacteria which generate the polymer by the microorganisms can be propagated after entering the stratum and meeting water, the volume is increased, and the pore throat is blocked. Compared with the existing particle type flow dividing stage, the problem of blockage caused by mismatching of particles and pore throats is avoided. The flow divider can effectively block the pore throat by expanding the volume per se according to the size of the pore throat; 2. the corrosion inhibitor added into the invention can form a corrosion inhibition film on the surface of the pipe column, so that the corrosion of the corrosion inhibitor to the pipe column is reduced, the operation of the pipe column can be realized without moving the pipe column, the construction steps are effectively simplified, and the construction risk and cost are reduced; 3. the added penetrating agent and surface active agent improve the permeability, are more beneficial to the flow dividing agent to enter fine passages of the stratum and improve the swept area.
[ example 3 ]
On the basis of embodiment 1 or embodiment 2, this embodiment provides a diverting agent, which is prepared from the following raw materials in percentage by weight, based on 100% of the total weight of the oil-soluble diverting temporary plugging agent:
75 percent of bacteria of a microorganism generated polymer, 3 percent of film-forming corrosion inhibitor, 3 percent of sulfo penetrant, 10 percent of alkylphenol polyoxyethylene ether nonionic surfactant and the balance of water.
In this embodiment, the bacteria that the microorganism generates the polymer are zoogloea, alkalophilic acid-producing bacteria, and the like;
the film-forming corrosion inhibitor is 2-thioketone-1-aminoethyl imidazoline;
the sulfogroup penetrant is polysiloxane sulfosuccinate;
the alkylphenol polyoxyethylene ether nonionic surfactant is Alkylphenol Polyoxyethylene (APEO).
The flow splitting agent is prepared by a preparation method comprising the following steps: the bacteria and the corrosion inhibitor are mixed according to a proportion at 60 ℃, and then the penetrant, the surfactant and the water are added at normal temperature and stirred uniformly.
[ example 4 ]
On the basis of embodiment 1 or embodiment 2, this embodiment provides a diverting agent, which is prepared from the following raw materials in percentage by weight, based on 100% of the total weight of the oil-soluble diverting temporary plugging agent:
80 percent of bacteria which are used for generating polymers by microorganisms, 4 percent of film-forming corrosion inhibitor, 5 percent of sulfo penetrant, 10 percent of alkylphenol polyoxyethylene ether nonionic surfactant and the balance of water.
In this embodiment, the bacteria that the microorganism generates the polymer are zoogloea, alkalophilic acid-producing bacteria, and the like;
the film-forming corrosion inhibitor is 2-thioketone-1-aminoethyl imidazoline;
the sulfogroup penetrant is polysiloxane sulfosuccinate;
the alkylphenol polyoxyethylene ether nonionic surfactant is Alkylphenol Polyoxyethylene (APEO).
The flow splitting agent is prepared by a preparation method comprising the following steps: the bacteria and the corrosion inhibitor are mixed according to a proportion at 60 ℃, and then the penetrant, the surfactant and the water are added at normal temperature and stirred uniformly.
[ example 5 ]
On the basis of embodiment 1 or embodiment 2, this embodiment provides a diverting agent, which is prepared from the following raw materials in percentage by weight, based on 100% of the total weight of the oil-soluble diverting temporary plugging agent:
77% of bacteria which are used for generating polymers by microorganisms, 3% of film-forming corrosion inhibitor, 4% of sulfo penetrant, 12% of alkylphenol polyoxyethylene ether nonionic surfactant and the balance of water.
In this embodiment, the bacteria that the microorganism generates the polymer are zoogloea, alkalophilic acid-producing bacteria, and the like;
the film-forming corrosion inhibitor is 2-thioketone-1-aminoethyl imidazoline;
the sulfogroup penetrant is polysiloxane sulfosuccinate;
the alkylphenol polyoxyethylene ether nonionic surfactant is Alkylphenol Polyoxyethylene (APEO).
The flow splitting agent is prepared by a preparation method comprising the following steps: the bacteria and the corrosion inhibitor are mixed according to a proportion at 60 ℃, and then the penetrant, the surfactant and the water are added at normal temperature and stirred uniformly.
[ example 6 ]
In the third step, the theoretical dosing time is calculated by collecting data of daily water injection amount and corresponding daily oil pressure after the last injection of the pressure-reducing and injection-increasing agent, drawing a fitting curve of the ratio of the daily water injection amount to the oil pressure and time,
in the formula: t is theoretical dosing time;
qwthe daily water injection amount of the water injection well;
k is the slope of a fitting curve of the ratio of the water injection amount to the oil pressure and the time after the last measure of the pressure reduction and injection increase of the bet takes effect;
b is the ratio of the water injection amount to the oil pressure after the last measure of the pressure-reducing and injection-increasing agent is effective;
t0after the measures of the last-time bet pressure reduction and increasing injection of the medicament are taken, the measures take effect for a long time.
And after a fitting curve of the ratio of daily water injection amount to oil pressure and time is drawn, removing abnormal points from the fitting curve, carrying out normalization treatment and carrying out rarefaction treatment to obtain a new fitting curve, and taking the slope of the new fitting curve as k.
As shown in FIG. 1, the development layer of the Ralo 1 block J1 well in Ji tableland is 8 th1Since the development, the ratio of daily water injection amount to oil pressure and the time are in a better linear relationship, the injection increasing measures are carried out in 4 months in 2017, the measures in 6 months in 2017 take effect, the ratio of the daily water injection amount to the oil pressure is increased correspondingly, namely t is t in 6 months in 20170The oil pressure at this time was 5.38MPa, and the daily water injection rate was 15 MPa. The ratio of the daily water injection amount to the oil pressure is increased, but the value is gradually reduced along with the extension of the development time, the reduction amplitude (0.0009) is smaller than the amplitude before measure (0.0013), and the daily water injection amount in 7 months in 2018 is 11m3D, well head pressure (oil pressure) is 16.4MPa, and the ratio of daily water injection quantity to oil pressure is 0.67m3And (d.MPa), the water injection well corresponds to 4 oil wells at the same layer, the initial wellhead fracture pressure of the 4 oil wells is 22.2MPa, 22.5MPa, 25.5MPa and 23.7MPa respectively, namely the minimum fracture pressure of the J1 well corresponding to the same layer of the oil well is 22.2 MPa.
2545 days is equal to about 6.9 years and equal to about 11 months of 6 years, then on the basis of 6 months of 2017, 11 months of 6 years are added, and 5 months of 2024 are obtained. The theoretical administration time is 2024 years and 5 months.
The steps and processes not described in detail in this embodiment are all common means, and are not described in detail here. The raw materials of the related reagents can be directly purchased in the market.
Claims (7)
1. A method for adding a pressure-reducing and injection-increasing medicament is characterized by comprising the following steps:
firstly, acquiring the minimum fracture pressure P of the oil well corresponding to the same layer position of the water injection welleAs threshold pressure;
secondly, detecting the bottom hole pressure of the water injection well;
thirdly, when the water injection well is about to reach the threshold pressure and corresponds to a multilayer underinjection well with a high water-containing well in the oil well, a pressure-reducing and injection-increasing medicament is not injected, and a flow-dividing acidification technology is adopted to carry out acidification and injection-increasing on the side direction of the crack so as to plug the crack channel;
when the water injection well is about to reach the threshold pressure and a single-layer underclothing well with a low water-containing well is arranged corresponding to the oil well, a local pressurization device is installed on a well site, and then a pressure-reducing injection-increasing medicament is added into a medicament adding tank of the local pressurization device;
when the water injection well is an under-injection well which does not reach the threshold pressure and has a low water-containing well corresponding to the oil well and the oil pressure is low, a pressure-reducing and injection-increasing medicament is not injected, a local pressurization device is installed on a well site, and the oil pressure of the water injection well is increased to be 2-3 MPa lower than the threshold pressure;
when the water injection well is a non-underpinning injection well which has been injected with the blood pressure reducing and injection increasing medicament before, calculating theoretical medicine adding time t, installing a local pressurization device, and adding the blood pressure reducing and injection increasing medicament 3-4 months before the theoretical medicine adding time t;
in the third step, in the shunting acidification technology, shunting agents are used, and the shunting agents comprise 75-80% of bacteria for generating polymers by microorganisms in the malt, 3-5% of film-forming corrosion inhibitors, 3-5% of sulfo penetrants and 10-14% of alkylphenol polyoxyethylene ether nonionic surfactants by mass.
2. The method for adding the antihypertensive and injection-increasing medicament according to claim 1, characterized in that: the pressure-reducing injection-increasing medicament is one of a molecular membrane surfactant, a hetero-gemini surfactant or a nano oil-displacing agent.
3. The method for adding the antihypertensive and injection-increasing medicament according to claim 1, characterized in that: the pressure-reducing injection-increasing medicament is prepared by mixing a heterogemini surfactant and a long-acting clay stabilizer, when the mineral content of the reservoir clay is up to more than 20%, the reservoir clay is medium water-sensitive, and the volume ratio of the heterogemini surfactant to the long-acting clay stabilizer is 2: 1; when the content of the reservoir clay mineral is lower than 20%, the reservoir clay is free or weak in water sensitivity, and the volume ratio of the hetero-gemini surfactant to the long-acting clay stabilizer is 3: 1.
4. the method for adding the antihypertensive and injection-increasing medicament according to claim 1, characterized in that: in the third step, when the water injection well is an insufficient injection well which does not reach the threshold pressure and is treated, the water well is still insufficient injection, a pressure-reducing injection-increasing medicament is added, and the mass ratio of the medicament to the injected water is 0.5: 100-1: 100, and continuously adding the medicine for at least 3 months.
5. The method for adding the antihypertensive and injection-increasing medicament according to claim 1, characterized in that: in the third step, when the pressure-reducing injection-increasing medicament is added, the mass ratio of the pressure-reducing injection-increasing medicament to the injected water is 0.5: 100-1: 100, and continuously adding the medicine for at least 3 months.
6. The method for adding the antihypertensive and injection-increasing medicament according to claim 1, characterized in that: in the third step, the theoretical dosing time is calculated by collecting data of daily water injection amount and corresponding daily oil pressure after the last injection of the pressure-reducing and injection-increasing agent, drawing a fitting curve of the ratio of the daily water injection amount to the oil pressure and time,
in the formula: t is theoretical dosing time;
qwthe daily water injection amount of the water injection well;
k is the slope of a fitting curve of the ratio of the water injection amount to the oil pressure and the time after the last measure of the pressure reduction and injection increase of the bet takes effect;
b is the ratio of the water injection amount to the oil pressure after the last measure of the pressure-reducing and injection-increasing agent is effective;
t0after the measures of the last-time bet pressure reduction and increasing injection of the medicament are taken, the measures take effect for a long time.
7. The method for adding the blood pressure-reducing and injection-increasing medicament according to claim 6, characterized in that: and after a fitting curve of the ratio of daily water injection amount to oil pressure and time is drawn, removing abnormal points from the fitting curve, carrying out normalization treatment and carrying out rarefaction treatment to obtain a new fitting curve, and taking the slope of the new fitting curve as k.
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