CN110952952B - Low-permeability reservoir deep profile control and flooding method - Google Patents
Low-permeability reservoir deep profile control and flooding method Download PDFInfo
- Publication number
- CN110952952B CN110952952B CN201911308708.2A CN201911308708A CN110952952B CN 110952952 B CN110952952 B CN 110952952B CN 201911308708 A CN201911308708 A CN 201911308708A CN 110952952 B CN110952952 B CN 110952952B
- Authority
- CN
- China
- Prior art keywords
- slug
- oil
- flooding
- profile control
- water
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000000034 method Methods 0.000 title claims abstract description 27
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 56
- 238000002347 injection Methods 0.000 claims abstract description 45
- 239000007924 injection Substances 0.000 claims abstract description 45
- 239000004005 microsphere Substances 0.000 claims abstract description 35
- 229920000642 polymer Polymers 0.000 claims abstract description 35
- 239000004908 Emulsion polymer Substances 0.000 claims abstract description 26
- 239000004094 surface-active agent Substances 0.000 claims abstract description 26
- 238000006073 displacement reaction Methods 0.000 claims abstract description 23
- 230000035699 permeability Effects 0.000 claims abstract description 12
- 239000011148 porous material Substances 0.000 claims abstract description 12
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 7
- 239000003921 oil Substances 0.000 claims description 48
- 235000019198 oils Nutrition 0.000 claims description 48
- 229940051841 polyoxyethylene ether Drugs 0.000 claims description 15
- 229920000056 polyoxyethylene ether Polymers 0.000 claims description 15
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims description 12
- 239000004372 Polyvinyl alcohol Substances 0.000 claims description 10
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 10
- 229920002451 polyvinyl alcohol Polymers 0.000 claims description 10
- 239000008139 complexing agent Substances 0.000 claims description 7
- DUIOKRXOKLLURE-UHFFFAOYSA-N 2-octylphenol Chemical compound CCCCCCCCC1=CC=CC=C1O DUIOKRXOKLLURE-UHFFFAOYSA-N 0.000 claims description 6
- GQOKIYDTHHZSCJ-UHFFFAOYSA-M dimethyl-bis(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C=CC[N+](C)(C)CC=C GQOKIYDTHHZSCJ-UHFFFAOYSA-M 0.000 claims description 6
- NWGKJDSIEKMTRX-AAZCQSIUSA-N Sorbitan monooleate Chemical group CCCCCCCC\C=C/CCCCCCCC(=O)OC[C@@H](O)[C@H]1OC[C@H](O)[C@H]1O NWGKJDSIEKMTRX-AAZCQSIUSA-N 0.000 claims description 5
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 claims description 5
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 5
- 239000003945 anionic surfactant Substances 0.000 claims description 5
- 235000019864 coconut oil Nutrition 0.000 claims description 5
- 239000003240 coconut oil Substances 0.000 claims description 5
- 235000014113 dietary fatty acids Nutrition 0.000 claims description 5
- 239000000194 fatty acid Substances 0.000 claims description 5
- 229930195729 fatty acid Natural products 0.000 claims description 5
- 150000004665 fatty acids Chemical class 0.000 claims description 5
- 239000007788 liquid Substances 0.000 claims description 4
- 239000002270 dispersing agent Substances 0.000 claims description 3
- 239000003995 emulsifying agent Substances 0.000 claims description 3
- 239000003999 initiator Substances 0.000 claims description 3
- 239000000178 monomer Substances 0.000 claims description 3
- MIULRUDFYYKSJQ-UHFFFAOYSA-N (4-hydroxy-2-oxo-1,3,2lambda5-dioxaphospholan-2-yl) dihydrogen phosphate Chemical compound C1C(OP(=O)(O1)OP(=O)(O)O)O MIULRUDFYYKSJQ-UHFFFAOYSA-N 0.000 claims description 2
- FDGBQHCDMSYZRC-UHFFFAOYSA-N 2-hydroxy-2-oxo-1,3,2$l^{5}-dioxaphosphinan-4-amine Chemical compound NC1CCOP(O)(=O)O1 FDGBQHCDMSYZRC-UHFFFAOYSA-N 0.000 claims description 2
- RPNUMPOLZDHAAY-UHFFFAOYSA-N Diethylenetriamine Chemical compound NCCNCCN RPNUMPOLZDHAAY-UHFFFAOYSA-N 0.000 claims description 2
- 229910019142 PO4 Inorganic materials 0.000 claims description 2
- VWCFCFOIUSKKSC-UHFFFAOYSA-N ethane-1,2-diamine;2-hydroxy-1,3,2$l^{5}-dioxaphosphepane 2-oxide Chemical compound NCCN.OP1(=O)OCCCCO1 VWCFCFOIUSKKSC-UHFFFAOYSA-N 0.000 claims description 2
- 238000012688 inverse emulsion polymerization Methods 0.000 claims description 2
- 238000004519 manufacturing process Methods 0.000 claims description 2
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 claims description 2
- 239000010452 phosphate Substances 0.000 claims description 2
- 239000002077 nanosphere Substances 0.000 claims 1
- 239000003129 oil well Substances 0.000 abstract description 7
- 238000011084 recovery Methods 0.000 abstract description 6
- 230000008901 benefit Effects 0.000 abstract description 3
- 239000000499 gel Substances 0.000 description 14
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 8
- 238000003756 stirring Methods 0.000 description 7
- 238000006116 polymerization reaction Methods 0.000 description 6
- 238000006243 chemical reaction Methods 0.000 description 5
- 229910052757 nitrogen Inorganic materials 0.000 description 4
- 239000000126 substance Substances 0.000 description 4
- 239000007864 aqueous solution Substances 0.000 description 3
- 239000003054 catalyst Substances 0.000 description 3
- 239000007863 gel particle Substances 0.000 description 3
- 238000010438 heat treatment Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 2
- 230000005465 channeling Effects 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- NFDRPXJGHKJRLJ-UHFFFAOYSA-N edtmp Chemical class OP(O)(=O)CN(CP(O)(O)=O)CCN(CP(O)(O)=O)CP(O)(O)=O NFDRPXJGHKJRLJ-UHFFFAOYSA-N 0.000 description 2
- 239000012530 fluid Substances 0.000 description 2
- 239000000203 mixture Substances 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 229920002401 polyacrylamide Polymers 0.000 description 2
- 230000008569 process Effects 0.000 description 2
- VGGSQFUCUMXWEO-UHFFFAOYSA-N Ethene Chemical compound C=C VGGSQFUCUMXWEO-UHFFFAOYSA-N 0.000 description 1
- 239000005977 Ethylene Substances 0.000 description 1
- IAYPIBMASNFSPL-UHFFFAOYSA-N Ethylene oxide Chemical compound C1CO1 IAYPIBMASNFSPL-UHFFFAOYSA-N 0.000 description 1
- DDAQLPYLBPPPRV-UHFFFAOYSA-N [4-(hydroxymethyl)-2-oxo-1,3,2lambda5-dioxaphosphetan-2-yl] dihydrogen phosphate Chemical compound OCC1OP(=O)(OP(O)(O)=O)O1 DDAQLPYLBPPPRV-UHFFFAOYSA-N 0.000 description 1
- 239000002250 absorbent Substances 0.000 description 1
- 230000009471 action Effects 0.000 description 1
- 238000005273 aeration Methods 0.000 description 1
- 229910052782 aluminium Inorganic materials 0.000 description 1
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000004132 cross linking Methods 0.000 description 1
- 239000003431 cross linking reagent Substances 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 230000001186 cumulative effect Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 230000018044 dehydration Effects 0.000 description 1
- 238000006297 dehydration reaction Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 150000002191 fatty alcohols Chemical class 0.000 description 1
- 229910052742 iron Inorganic materials 0.000 description 1
- 235000015110 jellies Nutrition 0.000 description 1
- 239000008274 jelly Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- -1 phenolic aldehyde Chemical class 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000010865 sewage Substances 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 230000001954 sterilising effect Effects 0.000 description 1
- 238000004659 sterilization and disinfection Methods 0.000 description 1
- 230000008685 targeting Effects 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
-
- 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
- C09K8/584—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
-
- 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
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Materials Engineering (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Geochemistry & Mineralogy (AREA)
- Manufacturing Of Micro-Capsules (AREA)
Abstract
The invention discloses a low permeability reservoir deep profile control and flooding method, which comprises the following steps: step 1: designing injection quantity, injection speed and injection pressure of the profile control agent according to daily water injection data of a water injection well; step 2: preparing an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant oil flooding slug according to the calculated amount in the step 1; and step 3: injecting an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant oil displacement slug into the target oil displacement well in sequence through a water injection pipeline; and 4, step 4: the invention utilizes polymer microspheres to block oil layer cracks and large pore canals, enlarge swept volume, utilize surfactant to displace residual oil in the oil layer, select polymer microspheres as main body section plugs, give full play to the advantage of polymer microspheres entering deep part of the oil layer to displace residual oil, improve the deep part of the oil layer water-flooding unevenness and displace residual oil, and realize the purpose of improving the recovery ratio of the oil well.
Description
Technical Field
The invention relates to the technical field of oil exploitation, in particular to a method for deep profile control and flooding of a low-permeability reservoir.
Background
The exploratory reserves of low-permeability oil reservoirs in China account for 70% of the total exploratory reserves and become the main field of crude oil exploitation. The low permeability reservoir has the characteristics of large reserve capacity scale, low abundance, compact reservoir, high mining technical requirements and the like. In the low permeability reservoir water injection development process, due to the existence of reservoir heterogeneity and cracks, the injected water is unevenly propelled to easily form a dominant water flow channel or suddenly advances along the cracks, so that the water content of the oil well continuously rises, and the chemical profile control process technology becomes a main means for controlling the water content of the oil well to rise.
The ZL201210015473.X patent discloses a method for injecting a jelly profile control agent into cracks by suspending and carrying water-absorbent resin particles and water-insoluble solid particles, and an aluminum gel profile control and flooding agent disclosed in the CN104140801A patent, a profile control and flooding composition disclosed in the CN104650842A patent, a profile control and flooding method and the like are metal cross-linked or phenolic aldehyde cross-linked weak gels, the method uses the weak gels as main agents for profile control, and the method mainly has two defects: firstly, a weak gel system is formed by preparing a plurality of groups of polyacrylamide, a cross-linking agent and the like and then injecting the mixture into the underground to form gel, and the gel forming performance of the weak gel system is influenced by the oil reservoir environment and is difficult to control; secondly, the gel system is affected by the mineralization degree of the oil reservoir due to the linear crosslinking of polyacrylamide, molecular chain curling and gel dehydration are generated, so that the effective period of measures is short, and the aim of improving the deep water drive of the oil reservoir and increasing the recovery ratio cannot be achieved.
Moreover, one of the main reasons for the low recovery efficiency of water-flooding reservoirs is that the sweep efficiency of water-flooding is low; one important factor affecting water flooding efficiency is non-homogeneity; the high-permeability pore channel type oil deposit has the characteristics of high permeability, wide pore throat and micro-crack development, and has heterogeneity due to the complexity of a pore structure and the surface property of rocks. When water drive is carried out on a non-homogeneous stratum, the propulsion of the displacement fluid cannot uniformly advance in a piston mode, so that the injected displacement fluid suddenly advances along a high-permeability stratum section, and a local water channeling phenomenon occurs, so that the swept efficiency of the injected water is reduced, and the water drive recovery ratio is restricted. In the traditional method, a pore passage is blocked and then water drive is carried out, in the method, simple profile control and subsequent water drive are difficult to adapt to the complexity of a reservoir stratum, so that the phenomena of small-scale water channeling, fingering and the like after blocking are caused, and the difficulty in further improving the water drive use degree is higher.
Therefore, aiming at the problem that the high-permeability channel of the low-permeability reservoir is relatively developed, a new method for deep profile control and flooding of the low-permeability reservoir is urgently needed.
Disclosure of Invention
In view of the above technical problems, the present invention aims to provide a multi-element composite targeting deep profile control method for the problem of relatively developing high-permeability channels of low-permeability reservoirs, which can realize high-dosage injection of profile control agent, improve the nonuniform deep water flooding of reservoirs and finally increase the recovery ratio.
A low permeability reservoir deep profile control and flooding method comprises the following steps:
step 1: designing injection quantity, injection speed and injection pressure of the profile control agent according to daily water injection data of a water injection well;
step 2: preparing an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant oil-displacing slug according to the calculated amount in the step 1, wherein the prepared water is oil field sewage or clear water, and when the prepared water does not meet the oil field reinjection water standard, the prepared water is subjected to iron removal, sterilization and aeration treatment;
and step 3: injecting an emulsion polymer preposed slug, a polymer nano microsphere main slug and a surfactant oil displacement slug into the target drive and adjustment well in sequence through a water injection pipeline, wherein the next slug can be injected only after the former slug is completely injected into the target drive and adjustment well;
and 4, step 4: and carrying out subsequent conventional injection and production operation.
Further, the daily injection amount of the emulsion polymer preposed slug and the surfactant oil displacement slug is 1.5 to 2 times of the daily injection amount of the target profile control and flooding well, the daily injection amount of the polymer nano microsphere main slug is 1.5 times of the daily injection amount of the target profile control and flooding well, and the cumulative total injection amount of the emulsion polymer, the polymer nano microsphere and the surfactant is 0.2 to 0.5 time of the oil layer pore volume controlled by the target profile control and flooding well in terms of volume ratio; the total filling proportion of the emulsion polymer front slug, the polymer nano microsphere main slug and the surfactant oil displacement slug is as follows: 1:10-20:1-5.
Further, the emulsion polymer front slug comprises the following components in percentage by mass: the monomer is 0.1-0.5% of acrylamide and 0.05-0.4% of dimethyl diallyl ammonium chloride, the emulsifier is 0.2-0.6% of span 80, the initiator is 0.01-0.04% of ammonium persulfate, the dispersant is 0.5-3% of polyvinyl alcohol and octyl phenol polyoxyethylene ether, the ratio of the polyvinyl alcohol to the octyl phenol polyoxyethylene ether is 1:1, 20-40% of white oil is oil phase base liquid, the balance is water, and the water is water phase base liquid, and the monomer is synthesized by adopting an inverse emulsion polymerization method. The preparation method of the emulsion polymer front slug comprises the following steps: adding the emulsifier, the dispersant and the white oil into a reactor with a stirrer in proportion, uniformly stirring, adding the prepared acrylamide and dimethyl diallyl ammonium chloride solution, introducing nitrogen for 30min, heating to 70 ℃, adding the initiator, reacting for 6h to obtain the product, and continuously stirring in the whole reaction process.
Further, the polymer nano microsphere main section plug comprises the following components in percentage by mass: 1-5% of polymer nano-microspheres and the balance of water, wherein the polymer nano-microspheres are acrylamide pre-crosslinked gel. The main section plug action mechanism of the polymer nano microsphere is to block oil layer cracks and large pores, enlarge swept volume and adjust plane and in-layer heterogeneity.
Further, the surfactant oil displacement slug comprises the following components in percentage by mass: 0.2 to 0.8 percent of high-grade fatty alcohol-polyoxyethylene ether sulfate anionic surfactant, 0.5 to 2 percent of coconut oil fatty acid diethanolamide and 2 to 8 percent of organophosphorus complexing agent.
Further, the organophosphorus complexing agent comprises at least one of ethylenediamine tetramethylene phosphate, diethylenetriamine pentamethyl phosphate, aminotrimethylene phosphate or hydroxyethylene diphosphate.
The invention has the beneficial effects that:
the invention provides a method for deep profile control and flooding of a low-permeability oil reservoir, which achieves the purposes of deep plugging and profile control and flooding by sequentially injecting an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant flooding slug into the oil reservoir: the emulsion polymer front slug is utilized to pretreat the stratum, so that the stratum adsorption capacity is reduced, the main slug is not diluted by stratum water, and the extremely poor permeability of an oil layer can be adjusted, thereby being more beneficial to the main slug to play a role; the polymer microspheres are used for plugging oil layer cracks and large pores and expanding swept volume, the advantage that the polymer microspheres enter the deep part of an oil layer to displace residual oil is fully exerted, and the water drive unevenness at the deep part of the oil layer is improved; and the surfactant is used for displacing the residual oil in the oil layer, so that the aim of improving the recovery ratio of the oil well is finally fulfilled.
Detailed Description
The technical solutions of the present invention will be described in detail below in order to clearly understand the technical features, objects, and advantages of the present invention, but the present invention is not limited to the practical scope of the present invention.
Example 1
Daily water injection rate of 3-port profile control and flooding well of certain oil field is 100m3Total underground pore volume of 50000m3Design total injection of 0.2PV, i.e. 10000m3. Sequentially injecting an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant oil displacement slug into a target profile control and flooding well through a water injection well, wherein the daily injection amount of each slug is 150m3、150m3、200m3The total injection quantity of each slug is 500m in sequence3、7500m3、2000m3；
The emulsion polymer pre-slug comprises the following components: according to the mass ratio, 0.35% of span 80, 1.5% of polyvinyl alcohol, 1: 1% of octylphenol polyoxyethylene ether and 25% of white oil are added into a reaction kettle and continuously stirred, wherein the polymerization degree of the polyvinyl alcohol is 1500-1600, the polymerization degree of the octylphenol polyoxyethylene ether is 6, after uniform stirring, an aqueous solution prepared from 0.25% of acrylamide, 0.3% of dimethyl diallyl ammonium chloride and 72.575% of water is added, nitrogen is introduced for 30min, the temperature is raised to 70 ℃, 0.025% of ammonium persulfate is added, and the reaction is carried out for 6 hours, thus obtaining the catalyst.
The polymer nano microsphere main section plug comprises the following components: 4% of acrylamide pre-crosslinked gel and 96% of water in percentage by mass, wherein the acrylamide pre-crosslinked gel is HJK-3 pre-crosslinked gel particles, Beijing Hexagon chemical industry group, LLC;
the surfactant flooding slug comprises the following components: according to the mass ratio, 0.4% of C13 higher fatty alcohol polyoxyethylene ether sulfate anionic surfactant has the molecular formula: CH3(CH2) xO (CH2CH2O) y-SO3 -X is 12 and y is 3; 2% coconut oil fatty acid diethanolamide; 5% of organophosphorus complexing agent: ethylenediaminetetramethylenephosphonic acid salts;
by sequentially injecting the emulsion polymer front slug, the polymer nano microsphere main slug and the surfactant oil displacement slug into an oil layer, the yield of the area is shown in the table 1 before and after the displacement by the displacement and regulation method of the invention, and as can be seen from the table 1, the daily oil increase of 15.8 tons of corresponding single well group oil wells is realized after the displacement and regulation measures, and the water content is reduced by 12.7 percent.
TABLE 1
Example 2
The daily water injection rate of 3 ports of the oil field is 50m3The total underground pore volume is 20000m3Design total injection of 0.5PV, i.e. 10000m3. Sequentially injecting an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant oil displacement slug into a target profile control and flooding well through a water injection well, wherein the daily injection amount of each slug is 100m3、75m3、100m3The total injection quantity of each slug is 625m in sequence3、6250m3、3125m3。
The emulsion polymer pre-slug comprises the following components: adding 0.2% of span 80, 0.5% of polyvinyl alcohol, 0.5% of octyl phenol polyoxyethylene ether (1:1) and 20% of white oil into a reaction kettle according to the mass ratio, continuously stirring, wherein the polymerization degree of polyvinyl alcohol is 1500-1600, the polymerization degree of ethylene of the octyl phenol polyoxyethylene ether is 7, uniformly stirring, adding an aqueous solution prepared from 0.1% of acrylamide, 0.05% of dimethyl diallyl ammonium chloride and 79.14% of water, introducing nitrogen for 30min, heating to 70 ℃, adding 0.01% of ammonium persulfate, and reacting for 6 hours to obtain the catalyst.
The polymer nano microsphere main section plug comprises the following components: 1% of polymer nano-microspheres and 99% of water in percentage by mass, wherein the acrylamide pre-crosslinked gel is HJK-3 pre-crosslinked gel particles, Beijing Hexagon chemical industry group, Limited liability company;
the surfactant flooding slug comprises the following components: 0.2% by mass of C13The high-grade fatty alcohol-polyoxyethylene ether sulfate anionic surfactant has the molecular formula: CH3(CH2) xO (CH2CH2O) y-SO3 -X is 12 and y is 3; 0.5% coconut oil fatty acid diethanolamide; 2% of organophosphorus complexing agent: ethylenediaminetetramethylenephosphonic acid salts;
by sequentially injecting the emulsion polymer front slug, the polymer nano microsphere main slug and the surfactant oil displacement slug into an oil layer, the yield of the area is shown in the table 2 before and after the displacement regulation by the displacement regulation method of the invention, and as can be seen from the table 2, the oil increase of 17 tons of corresponding average single well group oil wells is realized after the displacement regulation measures, and the water content is reduced by 6.4 percent.
TABLE 2
Example 3
The daily water injection rate of 3 ports of the oil field is 60m3Total underground pore volume of 30000m3Design total injection of 0.5PV, i.e. 15000m3. Injecting 600m into a target profile control and flooding well in sequence through a water injection well3Emulsion Polymer front slug, 11400m3Main slug of polymer nano microsphere and 3000m3The surfactant oil-displacing slug, after the previous slug is completely injected, the next slug can be injected, and the daily injection quantity of every slug is 120m3、90m3、120m3。
The emulsion polymer pre-slug comprises the following components: adding 0.6% of span 80, 3% of polyvinyl alcohol and octylphenol polyoxyethylene ether (1:1) and 40% of white oil into a reaction kettle according to the mass ratio, continuously stirring, wherein the polymerization degree of polyvinyl alcohol is 1600-fold-1700, the polymerization degree of ethylene oxide of the octylphenol polyoxyethylene ether is 7, uniformly stirring, adding an aqueous solution prepared from 0.5% of acrylamide, 0.4% of dimethyl diallyl ammonium chloride and 55.46% of water, introducing nitrogen for 30min, heating to 70 ℃, adding 0.04% of ammonium persulfate, and reacting for 6 hours to obtain the catalyst.
The polymer nano microsphere main section plug comprises the following components: according to the mass ratio, 5% of polymer nano microspheres and 95% of water, wherein the acrylamide pre-crosslinked gel is HJK-3 pre-crosslinked gel particles, Beijing Hexagon chemical industry group, Limited liability company;
the surfactant flooding slug comprises the following components: 0.8% by mass of C16The high-grade fatty alcohol-polyoxyethylene ether sulfate anionic surfactant has the molecular formula: CH3(CH2) xO (CH2CH2O) y-SO3 -X is 15 and y is 3; 2% coconut oil fatty acid diethanolamide; 8% of organophosphorus complexing agent: (ii) hydroxyethylidene diphosphate;
by sequentially injecting the emulsion polymer front slug, the polymer nano microsphere main slug and the surfactant oil-displacing slug into an oil layer, the yield of the area is shown in the table 3 before and after the displacement and regulation by the displacement and regulation method of the invention, and as can be seen from the table 3, the oil increase of the corresponding average single-well group oil well is 12.8 tons after the displacement and regulation measures, and the water content is reduced by 4.6 percent.
TABLE 3
Various other modifications and changes may be made by those skilled in the art based on the above-described technical solutions and concepts, and all such modifications and changes should fall within the scope of the claims of the present invention.
Claims (6)
1. A low permeability reservoir deep profile control and flooding method is characterized by comprising the following steps:
step 1: calculating the total injection amount and the daily injection amount of the profile control agent according to daily water injection data of the water injection well;
step 2: preparing an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant oil flooding slug according to the calculated amount in the step 1;
and step 3: sequentially injecting an emulsion polymer front slug, a polymer nano microsphere main slug and a surfactant oil displacement slug into the target oil displacement and regulation well through a water injection pipeline;
and 4, step 4: performing subsequent conventional injection and production operation;
the daily injection amount of the emulsion polymer preposed slug and the surfactant flooding slug is 1.5 to 2 times of the daily injection amount of the target profile control and flooding well by volume, and the daily injection amount of the polymer nano microsphere main slug is 1.5 times of the daily injection amount of the target profile control and flooding well by volume;
the accumulated total injection amount of the emulsion polymer, the polymer nano-microspheres and the surfactant is 0.2-0.5 time of the pore volume of an oil layer controlled by a target profile control and flooding well in terms of volume;
the emulsion polymer front slug is prepared from the following components in percentage by mass: the monomer is 0.1-0.5% of acrylamide and 0.05-0.4% of dimethyl diallyl ammonium chloride, the emulsifier is span 80 with 0.2-0.6%, the initiator is 0.01-0.04% of ammonium persulfate, the dispersant is 0.5-3% of polyvinyl alcohol and octyl phenol polyoxyethylene ether, the ratio of the polyvinyl alcohol to the octyl phenol polyoxyethylene ether is 1:1, 20-40% of white oil is oil phase base liquid, the balance is water, the water is water phase base liquid, and the product is synthesized by adopting an inverse emulsion polymerization method.
2. The low permeability reservoir deep profile control and flooding method of claim 1, wherein the total filling ratio of the emulsion polymer pre-slug, the polymer nano microsphere main slug and the surfactant flooding slug is as follows by volume ratio: 1:10-20:1-5.
3. The low permeability reservoir deep profile control method of claim 1, wherein in step 3, the next slug is not injected until the previous slug is completely injected into the target profile control well.
4. The low permeability reservoir deep profile control method of claim 1, wherein the polymeric nanosphere main segment plug comprises the following components: 1-5% of polymer nano-microspheres and the balance of water by mass ratio, wherein the polymer nano-microspheres are acrylamide pre-crosslinked gel.
5. The low permeability reservoir deep profile control method of claim 1, wherein the surfactant flooding slug comprises the following components by mass: 0.2 to 0.8 percent of high-grade fatty alcohol-polyoxyethylene ether sulfate anionic surfactant, 0.5 to 2 percent of coconut oil fatty acid diethanolamide, 2 to 8 percent of organophosphorus complexing agent and the balance of water.
6. The low permeability reservoir deep flooding method of claim 5, wherein the organophosphorus complexing agent comprises at least one of ethylenediamine tetramethylene phosphate, diethylenetriamine pentamethyl phosphate, aminotrimethylene phosphate, or hydroxyethylene diphosphate.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911308708.2A CN110952952B (en) | 2019-12-18 | 2019-12-18 | Low-permeability reservoir deep profile control and flooding method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911308708.2A CN110952952B (en) | 2019-12-18 | 2019-12-18 | Low-permeability reservoir deep profile control and flooding method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN110952952A CN110952952A (en) | 2020-04-03 |
| CN110952952B true CN110952952B (en) | 2020-09-22 |
Family
ID=69982581
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201911308708.2A Active CN110952952B (en) | 2019-12-18 | 2019-12-18 | Low-permeability reservoir deep profile control and flooding method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN110952952B (en) |
Families Citing this family (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN111594116B (en) * | 2020-05-18 | 2021-10-22 | 中国石油大学(北京) | In-situ emulsification oil displacement method for low-permeability reservoir |
| CN114059978B (en) * | 2020-08-03 | 2024-05-07 | 中国石油化工股份有限公司 | Chemical cold recovery method for strong water-sensitive heavy oil reservoir |
| CN114427376B (en) * | 2020-09-22 | 2024-04-26 | 中国石油化工股份有限公司 | Method for enhancing lateral drive between wells of large-bottom water reservoir |
| CN114645690B (en) * | 2020-12-21 | 2024-03-26 | 中国石油化工股份有限公司 | Compound profile control and flooding process for gel dispersion |
| CN112877051B (en) * | 2021-02-09 | 2022-09-02 | 山东达维石油技术有限公司 | Compact oil reservoir phase-permeation profile control agent and preparation method thereof |
| CN112795374A (en) * | 2021-04-12 | 2021-05-14 | 山东聚星石油科技有限公司 | Temperature-resistant salt-resistant heterogeneous nano composite oil displacement system and preparation method and application thereof |
| CN115710490A (en) * | 2021-08-23 | 2023-02-24 | 中国石油天然气股份有限公司 | Composite slug deep profile control and flooding agent and preparation method and application thereof |
| CN117189049B (en) * | 2023-09-28 | 2024-04-23 | 大庆油田有限责任公司 | Nano profile control and flooding method suitable for low-permeability fractured reservoir |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4064943A (en) * | 1976-12-06 | 1977-12-27 | Shell Oil Co | Plugging permeable earth formation with wax |
| CN104612639B (en) * | 2015-01-28 | 2017-01-18 | 西安石油大学 | Process of deep profile control over low-permeability oil reservoir |
| CN106566484B (en) * | 2016-10-31 | 2018-08-28 | 中国石油大学(华东) | Fracture-type reservoir protective agent composition, the drilling fluid containing the fracture-type reservoir protective agent composition and its application |
| CN108166960B (en) * | 2018-01-16 | 2020-08-07 | 中国石油天然气股份有限公司 | Low-permeability oil reservoir step-by-step profile control and flooding process |
-
2019
- 2019-12-18 CN CN201911308708.2A patent/CN110952952B/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CN110952952A (en) | 2020-04-03 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN110952952B (en) | Low-permeability reservoir deep profile control and flooding method | |
| CN108166960B (en) | Low-permeability oil reservoir step-by-step profile control and flooding process | |
| CN109735315B (en) | Environment-friendly delayed crosslinking profile control agent for oil extraction and preparation method and application thereof | |
| CN102533240B (en) | High-temperature oil reservoir composite modifying and flooding agent and preparing method and application thereof | |
| CN110173251A (en) | Compact oil reservoir CO2Auxiliary energy-storage imbibition fracturing process | |
| CN109915093B (en) | Method for improving oil reservoir recovery ratio by integrating' plugging/regulating/flooding | |
| CN102174317A (en) | Profile control agent suitable for ASP flooding | |
| CN101314712A (en) | Microsphere oil displacement profile control agent, displacement of reservoir oil system and displacement of reservoir oil method | |
| CN109021159B (en) | Oil well water shutoff agent and preparation method and application thereof | |
| CN113136190B (en) | Thickened oil viscosity reduction oil displacement agent with profile control and flooding performance and preparation method thereof | |
| US3820603A (en) | Altering relative permeability in production wells | |
| CN116948079A (en) | Drag reducer for shale gas reservoir fracturing and preparation method thereof | |
| CN111648741A (en) | Chemical flooding method for medium-permeability reservoir | |
| CN111088008B (en) | Surfactant composition for pressure reduction and injection increase of low-permeability oil reservoir and preparation method and application thereof | |
| US7867952B2 (en) | Flexible polymer, particles prepared therefrom and process for preparing the same | |
| CN114482918A (en) | Profile control method for low-speed discontinuous injection | |
| CN114736330A (en) | Cucurbituril hybrid supramolecular polymer oil displacement agent and preparation method thereof | |
| CN110204641B (en) | Cross-linked polymer microsphere for profile control and preparation method thereof | |
| CN104277809A (en) | Oil-displacement composition and preparation method thereof | |
| CN101210487B (en) | Design method for increasing recovery efficiency technique | |
| CN107345132A (en) | A kind of compound rhythm oil reservoir Complex polymer type profile control agent and its application method | |
| CN110330958A (en) | A kind of method of profile control and acidification connection work improvement intake profile | |
| CN117070205B (en) | Pressure-reducing injection-increasing surfactant and preparation method thereof | |
| CN107338035A (en) | A kind of compound rhythm oil reservoir chromium aluminium ion Compositional type profile control agent and its application method | |
| CN118271525A (en) | Low-salt releasable nano core-shell material and preparation method and application thereof |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |