CN114622877A - Crude oil exploitation method for foam oil reservoir - Google Patents
Crude oil exploitation method for foam oil reservoir Download PDFInfo
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- CN114622877A CN114622877A CN202011448574.7A CN202011448574A CN114622877A CN 114622877 A CN114622877 A CN 114622877A CN 202011448574 A CN202011448574 A CN 202011448574A CN 114622877 A CN114622877 A CN 114622877A
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- Prior art keywords
- oil reservoir
- foam
- solution
- threshold
- reservoir
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- 239000003921 oil Substances 0.000 title claims abstract description 265
- 239000006260 foam Substances 0.000 title claims abstract description 159
- 238000000034 method Methods 0.000 title claims abstract description 75
- 239000010779 crude oil Substances 0.000 title claims abstract description 58
- 238000011084 recovery Methods 0.000 claims abstract description 36
- 238000004519 manufacturing process Methods 0.000 claims abstract description 30
- 238000010438 heat treatment Methods 0.000 claims abstract description 12
- 239000000243 solution Substances 0.000 claims description 151
- 229920000642 polymer Polymers 0.000 claims description 62
- 239000007789 gas Substances 0.000 claims description 48
- 239000002253 acid Substances 0.000 claims description 36
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 claims description 33
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 claims description 32
- 239000002904 solvent Substances 0.000 claims description 29
- 239000003381 stabilizer Substances 0.000 claims description 29
- 238000005187 foaming Methods 0.000 claims description 27
- 239000012530 fluid Substances 0.000 claims description 26
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims description 21
- 150000001412 amines Chemical class 0.000 claims description 20
- 150000003863 ammonium salts Chemical class 0.000 claims description 20
- 239000012266 salt solution Substances 0.000 claims description 18
- 239000000945 filler Substances 0.000 claims description 17
- 239000000725 suspension Substances 0.000 claims description 13
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 12
- RTZKZFJDLAIYFH-UHFFFAOYSA-N Diethyl ether Chemical compound CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 12
- 241000361919 Metaphire sieboldi Species 0.000 claims description 12
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 claims description 12
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 12
- 229920002401 polyacrylamide Polymers 0.000 claims description 12
- CPLXHLVBOLITMK-UHFFFAOYSA-N Magnesium oxide Chemical compound [Mg]=O CPLXHLVBOLITMK-UHFFFAOYSA-N 0.000 claims description 11
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 10
- 125000004432 carbon atom Chemical group C* 0.000 claims description 10
- 239000000377 silicon dioxide Substances 0.000 claims description 10
- 239000000230 xanthan gum Substances 0.000 claims description 10
- 229920001285 xanthan gum Polymers 0.000 claims description 10
- 229940082509 xanthan gum Drugs 0.000 claims description 10
- 235000010493 xanthan gum Nutrition 0.000 claims description 10
- 239000011231 conductive filler Substances 0.000 claims description 9
- XLOMVQKBTHCTTD-UHFFFAOYSA-N Zinc monoxide Chemical compound [Zn]=O XLOMVQKBTHCTTD-UHFFFAOYSA-N 0.000 claims description 8
- PMHQVHHXPFUNSP-UHFFFAOYSA-M copper(1+);methylsulfanylmethane;bromide Chemical compound Br[Cu].CSC PMHQVHHXPFUNSP-UHFFFAOYSA-M 0.000 claims description 8
- 239000000395 magnesium oxide Substances 0.000 claims description 8
- 239000002245 particle Substances 0.000 claims description 8
- HBMJWWWQQXIZIP-UHFFFAOYSA-N silicon carbide Chemical compound [Si+]#[C-] HBMJWWWQQXIZIP-UHFFFAOYSA-N 0.000 claims description 8
- 229910010271 silicon carbide Inorganic materials 0.000 claims description 8
- 235000012239 silicon dioxide Nutrition 0.000 claims description 8
- 150000004945 aromatic hydrocarbons Chemical class 0.000 claims description 7
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 7
- 238000004939 coking Methods 0.000 claims description 7
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 claims description 7
- 229930195734 saturated hydrocarbon Natural products 0.000 claims description 7
- 238000002791 soaking Methods 0.000 claims description 7
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 claims description 6
- 239000001569 carbon dioxide Substances 0.000 claims description 6
- 239000001294 propane Substances 0.000 claims description 6
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims description 5
- 239000001273 butane Substances 0.000 claims description 5
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 claims description 5
- 229910052757 nitrogen Inorganic materials 0.000 claims description 5
- 229910052582 BN Inorganic materials 0.000 claims description 4
- PZNSFCLAULLKQX-UHFFFAOYSA-N Boron nitride Chemical compound N#B PZNSFCLAULLKQX-UHFFFAOYSA-N 0.000 claims description 4
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 claims description 4
- 239000011148 porous material Substances 0.000 claims description 4
- 239000011787 zinc oxide Substances 0.000 claims description 4
- 238000000605 extraction Methods 0.000 abstract description 5
- 239000000295 fuel oil Substances 0.000 description 64
- 238000002347 injection Methods 0.000 description 22
- 239000007924 injection Substances 0.000 description 22
- 238000005065 mining Methods 0.000 description 18
- 230000008569 process Effects 0.000 description 17
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 9
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 6
- MUBZPKHOEPUJKR-UHFFFAOYSA-N Oxalic acid Chemical compound OC(=O)C(O)=O MUBZPKHOEPUJKR-UHFFFAOYSA-N 0.000 description 6
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 description 6
- UIIMBOGNXHQVGW-UHFFFAOYSA-M Sodium bicarbonate Chemical compound [Na+].OC([O-])=O UIIMBOGNXHQVGW-UHFFFAOYSA-M 0.000 description 6
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Chemical compound NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 description 6
- MRNZSTMRDWRNNR-UHFFFAOYSA-N bis(hexamethylene)triamine Chemical compound NCCCCCCNCCCCCCN MRNZSTMRDWRNNR-UHFFFAOYSA-N 0.000 description 6
- RPNUMPOLZDHAAY-UHFFFAOYSA-N Diethylenetriamine Chemical compound NCCNCCN RPNUMPOLZDHAAY-UHFFFAOYSA-N 0.000 description 5
- AXZKOIWUVFPNLO-UHFFFAOYSA-N magnesium;oxygen(2-) Chemical compound [O-2].[Mg+2] AXZKOIWUVFPNLO-UHFFFAOYSA-N 0.000 description 5
- 230000035699 permeability Effects 0.000 description 5
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 4
- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 description 4
- VKYKSIONXSXAKP-UHFFFAOYSA-N hexamethylenetetramine Chemical compound C1N(C2)CN3CN1CN2C3 VKYKSIONXSXAKP-UHFFFAOYSA-N 0.000 description 4
- TWNQGVIAIRXVLR-UHFFFAOYSA-N oxo(oxoalumanyloxy)alumane Chemical compound O=[Al]O[Al]=O TWNQGVIAIRXVLR-UHFFFAOYSA-N 0.000 description 4
- BWHMMNNQKKPAPP-UHFFFAOYSA-L potassium carbonate Chemical compound [K+].[K+].[O-]C([O-])=O BWHMMNNQKKPAPP-UHFFFAOYSA-L 0.000 description 4
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 3
- 230000009471 action Effects 0.000 description 3
- 239000004202 carbamide Substances 0.000 description 3
- 235000013877 carbamide Nutrition 0.000 description 3
- 229910052799 carbon Inorganic materials 0.000 description 3
- 238000006073 displacement reaction Methods 0.000 description 3
- 229910000030 sodium bicarbonate Inorganic materials 0.000 description 3
- 235000017557 sodium bicarbonate Nutrition 0.000 description 3
- 229910000029 sodium carbonate Inorganic materials 0.000 description 3
- VILCJCGEZXAXTO-UHFFFAOYSA-N 2,2,2-tetramine Chemical compound NCCNCCNCCN VILCJCGEZXAXTO-UHFFFAOYSA-N 0.000 description 2
- ZAXCZCOUDLENMH-UHFFFAOYSA-N 3,3,3-tetramine Chemical compound NCCCNCCCNCCCN ZAXCZCOUDLENMH-UHFFFAOYSA-N 0.000 description 2
- ATRRKUHOCOJYRX-UHFFFAOYSA-N Ammonium bicarbonate Chemical compound [NH4+].OC([O-])=O ATRRKUHOCOJYRX-UHFFFAOYSA-N 0.000 description 2
- LCGLNKUTAGEVQW-UHFFFAOYSA-N Dimethyl ether Chemical compound COC LCGLNKUTAGEVQW-UHFFFAOYSA-N 0.000 description 2
- GRYLNZFGIOXLOG-UHFFFAOYSA-N Nitric acid Chemical compound O[N+]([O-])=O GRYLNZFGIOXLOG-UHFFFAOYSA-N 0.000 description 2
- 108010039918 Polylysine Proteins 0.000 description 2
- 239000001099 ammonium carbonate Substances 0.000 description 2
- 235000012501 ammonium carbonate Nutrition 0.000 description 2
- 235000019270 ammonium chloride Nutrition 0.000 description 2
- RPHKINMPYFJSCF-UHFFFAOYSA-N benzene-1,3,5-triamine Chemical compound NC1=CC(N)=CC(N)=C1 RPHKINMPYFJSCF-UHFFFAOYSA-N 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 238000000354 decomposition reaction Methods 0.000 description 2
- 238000005485 electric heating Methods 0.000 description 2
- 239000004312 hexamethylene tetramine Substances 0.000 description 2
- 235000010299 hexamethylene tetramine Nutrition 0.000 description 2
- GKQPCPXONLDCMU-CCEZHUSRSA-N lacidipine Chemical compound CCOC(=O)C1=C(C)NC(C)=C(C(=O)OCC)C1C1=CC=CC=C1\C=C\C(=O)OC(C)(C)C GKQPCPXONLDCMU-CCEZHUSRSA-N 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 229910017604 nitric acid Inorganic materials 0.000 description 2
- 235000006408 oxalic acid Nutrition 0.000 description 2
- UKODFQOELJFMII-UHFFFAOYSA-N pentamethyldiethylenetriamine Chemical compound CN(C)CCN(C)CCN(C)C UKODFQOELJFMII-UHFFFAOYSA-N 0.000 description 2
- -1 polyimine Chemical compound 0.000 description 2
- 229920000656 polylysine Polymers 0.000 description 2
- 229910000027 potassium carbonate Inorganic materials 0.000 description 2
- FAGUFWYHJQFNRV-UHFFFAOYSA-N tetraethylenepentamine Chemical compound NCCNCCNCCNCCN FAGUFWYHJQFNRV-UHFFFAOYSA-N 0.000 description 2
- CTQNGGLPUBDAKN-UHFFFAOYSA-N O-Xylene Chemical compound CC1=CC=CC=C1C CTQNGGLPUBDAKN-UHFFFAOYSA-N 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000013043 chemical agent Substances 0.000 description 1
- 238000007872 degassing Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
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- 230000009467 reduction Effects 0.000 description 1
- 230000000717 retained effect Effects 0.000 description 1
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Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
- E21B43/164—Injecting CO2 or carbonated water
-
- 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
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
-
- 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
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
- E21B43/2401—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection by means of electricity
-
- 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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
Abstract
The invention provides a crude oil extraction method of a foam oil reservoir, which comprises the following steps: injecting the foam oil reservoir to make the oil reservoir pressure reach a preset value below the cap layer rupture pressure; heating the foam oil reservoir to excite the oil layer to generate gas and soak the well; and (5) well recovery is carried out and the daily oil production is controlled within a preset range. The crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention improves the recovery ratio of the foam oil reservoir.
Description
Technical Field
The invention relates to the technical field of oil exploitation, in particular to a crude oil exploitation method of a foam oil reservoir.
Background
The foam oil phenomenon refers to a phenomenon that dissolved gas is naturally contained in an oil reservoir, and the dissolved gas does not immediately separate from crude oil along with the reduction of the pressure of the oil reservoir in the natural exhaustion cold production process, but exists in the crude oil and flows together with the crude oil.
In the process of exploiting the foam oil reservoir, degassing characteristics of the foam oil reservoir have bubble point pressure and bubble point simulating pressure, wherein dissolved gas is distributed in crude oil between the bubble point and the bubble point simulating pressure to form foam oil, so that the viscosity of the crude oil is greatly reduced, and the flowing capacity of the crude oil and the production time and yield of natural failure cold recovery are improved. The viscosity of the degassed crude oil of the foam oil reservoir is 20000-50000 mPa.s, the flow resistance is extremely high, and the injected fluid is difficult to enter the deep part of the oil reservoir, so how to improve the recovery ratio of the foam oil in the later production period of natural failure becomes an important problem to be solved in the field.
Disclosure of Invention
Aiming at the problems in the prior art, the embodiment of the invention provides a crude oil exploitation method for a foam oil reservoir.
The invention provides a crude oil exploitation method of a foam oil reservoir, which comprises the following steps:
injecting the foam oil reservoir to make the oil reservoir pressure reach a preset value below the cap layer rupture pressure;
heating the foam oil reservoir to excite the oil layer to generate gas and soak the well;
and (5) well recovery is carried out and the daily oil production is controlled within a preset range.
Further, the injecting operation of the foam oil reservoir to enable the oil reservoir pressure to reach the preset value below the cap layer rupture pressure comprises the following steps:
injecting gas into the foam reservoir from a horizontal wellhead until the reservoir pressure reaches a first threshold below a cap layer fracture pressure;
injecting a suspension solution with heat-conducting fillers into the earthworm holes and the microcracks of the foam oil reservoir until the reservoir pressure reaches a second threshold value below the cap layer rupture pressure;
injecting a pre-solvent slug into the foam reservoir until the reservoir pressure reaches a third threshold below cap layer rupture pressure;
sequentially injecting fluid into the foam oil reservoir in a plug mode according to the sequence of an acid solution, a carbonate solution, an acid solution and a carbonate solution, or injecting a preset solution into the foam oil reservoir until the oil reservoir pressure reaches a fourth threshold value below the cap layer rupture pressure; wherein the preset solution is organic amine or ammonium salt solution;
injecting a sulfonate foaming solution with temperature resistance higher than a preset temperature into the foam oil reservoir until the oil reservoir pressure reaches the preset value below the cap layer rupture pressure; wherein, a polymer foam stabilizer is added into the sulfonate foaming solution;
wherein the first threshold is greater than the second threshold, the second threshold is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value.
Further, the first threshold is greater than 3MPa and equal to or less than 4 MPa.
Further, the second threshold unit is greater than 2MPa and equal to or less than 3 MPa.
Further, the heat conductive filler is at least one of alumina, magnesia, zinc oxide, aluminum nitride, boron nitride, and silicon carbide.
Further, the particle size of the heat-conducting filler is larger than 20 meshes and smaller than or equal to 200 meshes.
Further, the heat conducting filler is carried by a polymer solution, and the concentration of the polymer in the polymer solution is 0.1-3%.
Further, the polymer type in the polymer solution is at least one of polyacrylamide with the molecular weight of 100-2500 ten thousand, silicon dioxide with the molecular weight of 20-100 nm or xanthan gum.
Further, the injecting operation of the foam oil reservoir to enable the oil reservoir pressure to reach the preset value below the cap layer rupture pressure comprises the following steps:
injecting gas into the foam reservoir from a horizontal wellhead until the reservoir pressure reaches a set value below a cap layer rupture pressure;
injecting a pre-solvent slug into the foam reservoir until the reservoir pressure reaches a third threshold below cap layer rupture pressure;
sequentially injecting fluid into the foam oil reservoir in a plug mode according to the sequence of an acid solution, a carbonate solution, an acid solution and a carbonate solution, or injecting a preset solution into the foam oil reservoir until the oil reservoir pressure reaches a fourth threshold value below the cap layer rupture pressure; wherein the preset solution is organic amine or ammonium salt solution;
injecting a sulfonate foaming solution with temperature resistance higher than a preset temperature into the foam oil reservoir until the oil reservoir pressure reaches a preset value below the cap layer rupture pressure; wherein, a polymer foam stabilizer is added into the sulfonate foaming solution;
the set value is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value.
Further, the set value is 2.5MPa or more and 3MPa or less.
Further, the third threshold is greater than 1.5MPa and equal to or less than 2 MPa.
Further, the fourth threshold is greater than 1MPa and equal to or less than 1.5 MPa.
Further, the gas includes at least one of nitrogen, carbon dioxide, methane, ethane, propane, and butane.
Further, the solvent includes at least one of saturated hydrocarbon having 5 to 10 carbon atoms, aromatic hydrocarbon having 6 to 10 carbon atoms, alcohol and ether solvent.
Furthermore, the pore volume multiple number of each slug is equal and is 0.02-0.05 PV.
Further, the concentration of the acid solution slug is 5-20%.
Further, the concentration of the carbonate solution slug is 5% -20%.
Further, the concentration of the organic amine solution is 5-30%.
Further, the concentration of the ammonium salt solution is 5% -30%.
Further, the concentration of the sulfonate is 1% -3%; the concentration of the foam stabilizer is 0.1-1%; the type of the foam stabilizer is at least one of polyacrylamide with the molecular weight of 100-2500 ten thousand, silicon dioxide with the molecular weight of 20-100 nm or xanthan gum.
Further, the surface temperature of a heater used for heating the foam oil reservoir is 5-20 ℃ lower than the coking temperature of crude oil.
Furthermore, the number of days for soaking is 3-10 days.
Further, the preset value is greater than or equal to 0.5MPa and less than or equal to 1 MPa.
Further, the method further comprises:
and stopping production if the daily oil yield is judged to be less than the oil yield threshold value.
According to the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention, injection operation is carried out on the foam oil reservoir, so that the pressure of an oil layer reaches a preset value below the cover layer rupture pressure, the foam oil reservoir is heated to excite the oil layer to generate gas and anneal, the oil is recovered by opening a well, the daily oil yield is controlled within a preset range, an oil displacement medium can penetrate deep into the oil layer to displace oil through the injection operation, and the oil layer and fluid are heated by electric heating, so that the fluid flowing capacity and the yield are improved, the action range of the foam oil is expanded, and the recovery ratio of the foam oil reservoir is improved.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts. In the drawings:
fig. 1 is a schematic flow chart of a crude oil recovery method for a foam oil reservoir according to a first embodiment of the present invention.
Fig. 2 is a schematic flow chart of a crude oil recovery method for a foam oil reservoir according to a second embodiment of the present invention.
Fig. 3 is a schematic flow chart of a crude oil recovery method for a foam oil reservoir according to a third embodiment of the present invention.
FIG. 4 is a schematic representation of the downhole fluid distribution of a foam reservoir provided by a fourth embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the embodiments of the present invention are further described in detail below with reference to the accompanying drawings. The exemplary embodiments and descriptions of the present invention are provided to explain the present invention, but not to limit the present invention. It should be noted that the embodiments and features of the embodiments in the present application may be arbitrarily combined with each other without conflict.
In order to facilitate understanding of the technical solutions provided in the present application, the following first describes relevant contents of the technical solutions in the present application. The invention aims to provide a method for exploiting crude oil for greatly improving the recovery ratio in the middle and later periods of the exploitation of an overweight foam oil reservoir. The crude oil exploitation method for the foam oil reservoir provided by the embodiment of the invention aims at the heavy oil reservoir meeting the following conditions:
(1) the residual dissolved gas-oil ratio of the original oil reservoir containing gas and the oil layer before the scheme of the invention is implemented is more than 5m3/m3；
(2) The thickness of an oil layer is more than 3m, the oil saturation is more than 60%, the porosity is more than 30%, and the permeability is more than 1 darcy;
(3) horizontal well development is adopted, and the length of a horizontal section is more than 400 m.
Fig. 1 is a schematic flow chart of a crude oil recovery method for a foam oil reservoir according to a first embodiment of the present invention, and as shown in fig. 1, the crude oil recovery method for the foam oil reservoir according to the embodiment of the present invention includes:
s101, injecting the foam oil reservoir to enable the oil reservoir pressure to reach a preset value below the cover layer rupture pressure;
specifically, an oil displacement medium such as gas, a preposed solvent slug, fluid, foaming solution and the like is injected into the foam oil reservoir through injection operation to increase the oil reservoir pressure, so that the oil reservoir pressure reaches a preset value below the cap layer rupture pressure, namely the difference between the cap layer rupture pressure and the oil reservoir pressure is equal to the preset value. The preset value is set according to actual needs, and the embodiment of the invention is not limited. For example, the preset value is 0.5MPa or more and 1MPa or less.
S102, heating the foam oil reservoir to excite the oil reservoir to generate gas and soak the well;
specifically, after the injection operation of the foam oil reservoir is completed, an electric heater can be started to heat the foam oil reservoir, and the oil reservoir is excited by heating to generate gas, so that the well is sealed. Wherein, the power range per meter for heating the oil layer is 1000-2500W, which is set according to the actual requirement, and the embodiment of the invention is not limited. The electric heater is preconfigured. The time length of the blank well is set according to actual needs, and the embodiment of the invention is not limited. The foam oil reservoir is electrically heated to excite chemical reaction and generate gas in situ in the oil reservoir, so that the foam oil phenomenon in the oil reservoir is generated, and the problems that the reaction speed is low when a chemical agent is simply injected and a large amount of injected media is not reacted and is extracted in time of extraction are solved.
S103, well opening and recovery are carried out, and the daily oil production is controlled within a preset range;
specifically, after completion of the cased well, the well is opened for recovery. And in the process of exploiting the foam oil reservoir, counting the daily oil yield, controlling the daily oil yield and controlling the daily oil yield within a preset range. The preset range is set according to actual needs, and the embodiment of the invention is not limited. For example, the preset range is 20-100 t/d.
According to the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention, injection operation is carried out on the foam oil reservoir, so that the pressure of an oil layer reaches a preset value below the cover layer rupture pressure, the foam oil reservoir is heated to excite the oil layer to generate gas and anneal, the oil is recovered by opening a well, the daily oil yield is controlled within a preset range, an oil displacement medium can penetrate deep into the oil layer to displace oil through the injection operation, and the oil layer and fluid are heated by electric heating, so that the fluid flowing capacity and the yield are improved, the action range of the foam oil is expanded, and the recovery ratio of the foam oil reservoir is improved.
On the basis of the above embodiments, further, the method for extracting crude oil from a foam oil reservoir according to the embodiments of the present invention further includes:
and stopping production if the daily oil yield is judged to be less than the oil yield threshold value.
Specifically, the daily oil production is compared with an oil production threshold value, and if the daily oil production is less than the oil production threshold value, the production is stopped, namely the production of the foam oil reservoir is suspended. The oil production threshold is set according to practical experience, and the embodiment of the invention is not limited. For example, the oil production threshold is 2t/d or more and 5t/d or less.
Fig. 2 is a schematic flow chart of a crude oil recovery method for a foam oil reservoir according to a second embodiment of the present invention, and as shown in fig. 2, further, on the basis of the foregoing embodiments, the performing an injection operation on the foam oil reservoir to make the reservoir pressure reach a preset value below a cap fracture pressure includes:
s201, injecting gas into the foam oil reservoir from a horizontal well mouth until the oil reservoir pressure reaches a first threshold value below a cover layer fracture pressure;
specifically, gas is injected into the foam reservoir from a horizontal wellhead until the reservoir pressure reaches a first threshold value below a cap fracture pressure, and then gas injection is stopped, and the cap fracture pressure minus the reservoir pressure equals the first threshold value, so that reservoir microcracks are opened. Wherein the gas comprises at least one of nitrogen, carbon dioxide, methane, ethane, propane, and butane. The first threshold is set according to practical experience, and the embodiment of the invention is not limited. For example, the first threshold value is greater than 3MPa and equal to or less than 4 MPa.
Through injecting gas into the oil reservoir, let the oil reservoir produce the microcrack on the basis of current earthworm hole, let gas get into the oil reservoir deep, return from wider oil reservoir in the time of back production, improve the range of using, simultaneously, gas can also play the effect of supplementary stratum elastic energy, the production time of every round of extension.
S202, injecting a suspension solution with heat-conducting fillers into the earthworm holes and the microcracks of the foam oil reservoir until the oil reservoir pressure reaches a second threshold value below the cap layer rupture pressure;
specifically, after the reservoir pressure reaches a first threshold value below the cap fracture pressure, earthworm holes and microcracks of the foam reservoir can appear, a suspension solution with heat conducting fillers is injected into the earthworm holes and the microcracks of the foam reservoir to increase the heat conducting capacity of the foam reservoir, and the suspension solution is stopped from being injected until the reservoir pressure reaches a second threshold value below the cap fracture pressure, wherein the cap fracture pressure minus the reservoir pressure is equal to the second threshold value. Wherein the thermally conductive filler includes at least one of alumina, magnesia, zinc oxide, aluminum nitride, boron nitride, and silicon carbide, and has high thermal conductivity. The second threshold is set according to practical experience, and the embodiment of the present invention is not limited. For example, the second threshold value unit is greater than 2MPa and equal to or less than 3 MPa.
The heat conduction filler is filled in the microcracks and the earthworm holes, so that the heat transfer speed in the electrical heating process is greatly improved, the heating and temperature rising speed of an oil layer is accelerated, the reaction of an acid solution and a carbonate solution is greatly accelerated, and CO is generated2The gas speed is greatly accelerated, and the decomposition of organic amine or ammonium salt is greatly accelerated to generate NH3The gas velocity is increased, the viscosity of the crude oil is reduced by raising the temperature, the velocity of the generated gas dissolved in the crude oil is increased, and the generation of the foam oil phenomenon is accelerated.
For example, the particle size of the thermally conductive filler is 20 to 200 mesh. The concentration of the heat-conducting filler is 5-30%. The heat-conducting filler is carried by a polymer solution, the concentration of a polymer in the polymer solution is 0.1-3%, and the type of the polymer in the polymer solution is at least one of polyacrylamide with the molecular weight of 100-2500 ten thousand, 20-100 nm silicon dioxide or xanthan gum.
S203, injecting a preposed solvent slug into the foam oil reservoir until the oil reservoir pressure reaches a third threshold value below the cap layer rupture pressure;
specifically, a pre-solvent slug is injected into the foam reservoir until the reservoir pressure reaches a third threshold below the cap fracture pressure, at which time the cap fracture pressure minus the reservoir pressure equals the third threshold. The third threshold is set according to practical experience, and the embodiment of the present invention is not limited.
For example, the pre-solvent includes at least one of saturated hydrocarbon having 5 to 10 carbon atoms, aromatic hydrocarbon having 6 to 10 carbon atoms, alcohol and ether solvent. The third threshold value is greater than 1.5MPa and less than or equal to 2 MPa.
S204, sequentially injecting fluid in a plug mode into the foam oil reservoir according to the sequence of an acid solution, a carbonate solution, an acid solution and a carbonate solution, or injecting a preset solution into the foam oil reservoir until the oil layer pressure reaches a fourth threshold value below the cap layer fracture pressure; wherein the preset solution is organic amine or ammonium salt solution;
specifically, fluid is injected into the foam oil reservoir in a sequential and segmented mode, the injection sequence of the fluid is an acid solution, a carbonate solution, an acid solution and a carbonate solution, and the fluid injection is stopped until the reservoir pressure reaches a fourth threshold value below the cap fracture pressure, and at the moment, the cap fracture pressure minus the reservoir pressure is equal to the fourth threshold value. Or injecting a preset solution into the foam oil reservoir, and stopping injecting the fluid until the reservoir pressure reaches a fourth threshold value below the cap layer fracture pressure, wherein the fourth threshold value is equal to the cap layer fracture pressure minus the reservoir pressure. Wherein the preset solution is organic amine or ammonium salt solution. The fourth threshold is set according to practical experience, and the embodiment of the present invention is not limited. The fourth threshold is greater than 1MPa and equal to or less than 1.5 MPa.
The acid solution and the carbonate solution injected in a plug mode can enable the acid and the carbonate to be uniformly distributed into the oil layerPromoting the full decomposition reaction of acid and carbonate and increasing CO2The yield of (2).
For example, when fluid is injected in a slug mode, the pore volume multiple (PV) of each slug is equal and is 0.02-0.05 PV.
For example, the concentration of the acid solution slug is 5% to 20%, and the acid solution is preferably hydrochloric acid, acetic acid, nitric acid, hydrofluoric acid, or oxalic acid;
for example, the concentration of the carbonate solution slug is 5% to 20%, and the carbonate is preferably sodium carbonate, sodium bicarbonate or potassium carbonate.
For example, the concentration of the organic amine solution is 5% to 30%, and the organic amine solution is preferably diethylenetriamine, pentamethyldiethylenetriamine; hexamethylenetetramine; bis (hexamethylene) triamine; 1,3, 5-benzenetriamine; at least one of diethylenetriamine, triethylenetetramine, tetraethylenepentamine, bis (hexamethylene) triamine, polylysine, polyimine, dipropylenetriamine, tripropylenetetramine and bis (hexamethylene) triamine.
For example, the concentration of the ammonium salt solution is 5% to 30%, and the ammonium salt solution is preferably at least one of carbamide, ammonium carbonate and ammonium chloride.
S205, injecting a sulfonate foaming solution with temperature resistance higher than a preset temperature into the foam oil reservoir until the oil reservoir pressure reaches the preset value below the cap layer rupture pressure; wherein, a polymer foam stabilizer is added into the sulfonate foaming solution; wherein the first threshold is greater than the second threshold, the second threshold is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value.
Specifically, a sulfonate foaming solution which can resist temperature higher than a preset temperature is injected into the foam oil reservoir, a polymer foam stabilizer is added into the sulfonate foaming solution until the oil reservoir pressure reaches a preset value below the cap layer rupture pressure, and at the moment, the cap layer rupture pressure minus the oil reservoir pressure is equal to the preset value. Wherein the first threshold is greater than the second threshold, the second threshold is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value. The preset temperature is set according to actual needs, for example, set to 100 ℃, and the embodiment of the invention is not limited. The fourth threshold is set according to practical experience, and the embodiment of the present invention is not limited.
For example, the concentration of the sulfonate is 1 to 3 percent, the concentration of the polymer foam stabilizer is 0.1 to 1 percent, and the type of the foam stabilizer of the polymer foam stabilizer is at least one of polyacrylamide with the molecular weight of 100 to 2500 ten thousand, silicon dioxide with the molecular weight of 20 to 100nm or xanthan gum.
The injection of the temperature-resistant sulfonate foaming solution is beneficial to generating foam in a near-wellbore area in the production and recovery process, so that the gas output is restrained, the gas is promoted to be retained in an oil layer, the action range of the foam oil is improved, and the oil yield of each round is improved.
The step S201, the step S202, the step S203, the step S204, and the step S205 perform injection operation on the foam oil reservoir, and a process of making the oil layer pressure reach a preset value below the cap layer rupture pressure is a process adopted in the first injection operation of the foam oil reservoir.
In each of the above embodiments, the first threshold value is greater than 3MPa and not greater than 4 MPa.
In each of the above embodiments, the second threshold value unit is greater than 2MPa and equal to or less than 3 MPa.
On the basis of the above embodiments, further, the heat conductive filler is at least one of aluminum oxide, magnesium oxide, zinc oxide, aluminum nitride, boron nitride, and silicon carbide.
In addition to the above embodiments, the particle size of the heat conductive filler is larger than 20 mesh and not larger than 200 mesh.
On the basis of the above embodiments, further, the heat conductive filler is carried by a polymer solution, and the polymer concentration in the polymer solution is 0.1-3%.
On the basis of the above embodiments, further, the polymer type in the polymer solution is at least one of polyacrylamide with a molecular weight of 100 to 2500 ten thousand, silica with a molecular weight of 20 to 100nm, or xanthan gum.
Fig. 3 is a schematic flow chart of a crude oil recovery method for a foam oil reservoir according to a third embodiment of the present invention, and as shown in fig. 3, further, on the basis of the foregoing embodiments, the performing an injection operation on the foam oil reservoir to make the reservoir pressure reach a preset value below a cap fracture pressure includes:
s301, injecting gas into the foam oil reservoir from a horizontal wellhead until the oil reservoir pressure reaches a set value below the cap layer rupture pressure;
specifically, gas is injected into the foam reservoir from a horizontal wellhead until the reservoir pressure reaches a set value below the cap layer burst pressure, at which time the cap layer burst pressure minus the reservoir pressure equals the set value. Wherein the gas comprises at least one of nitrogen, carbon dioxide, methane, ethane, propane, and butane. The setting value is set according to practical experience, and the embodiment of the invention is not limited.
S302, injecting a preposed solvent slug into the foam oil reservoir until the oil reservoir pressure reaches a third threshold value below the cap layer rupture pressure;
specifically, the pre-solvent slug is injected into the foam reservoir until the reservoir pressure reaches a third threshold below the cap fracture pressure, at which time the cap fracture pressure minus the reservoir pressure equals the third threshold. The third threshold is set according to practical experience, and the embodiment of the present invention is not limited. The specific implementation process of this step is similar to step S203.
For example, the pre-solvent includes at least one of saturated hydrocarbon having 5 to 10 carbon atoms, aromatic hydrocarbon having 6 to 10 carbon atoms, alcohol and ether solvent.
S303, sequentially injecting fluid into the foam oil reservoir in a section plug mode according to the sequence of an acid solution, a carbonate solution, an acid solution and a carbonate solution, or injecting a preset solution into the foam oil reservoir until the oil reservoir pressure reaches a fourth threshold value below the cap layer rupture pressure; wherein the preset solution is organic amine or ammonium salt solution;
specifically, sequentially injecting fluids into the foam oil reservoir in a slug mode, wherein the injection sequence of the fluids is acid solution, carbonate solution, acid solution and carbonate solution, and stopping injecting the fluids until the reservoir pressure reaches a fourth threshold value below the cap fracture pressure, and at the moment, the cap fracture pressure minus the reservoir pressure is equal to the fourth threshold value. Or injecting a preset solution into the foam oil reservoir, and stopping injecting the fluid until the reservoir pressure reaches a fourth threshold value below the cap layer fracture pressure, wherein the fourth threshold value is equal to the cap layer fracture pressure minus the reservoir pressure. Wherein the preset solution is organic amine or ammonium salt solution. The third threshold is set according to practical experience, and the embodiment of the present invention is not limited. The specific implementation process of this step is similar to step S204.
S304, injecting a sulfonate foaming solution with temperature resistance higher than a preset temperature into the foam oil reservoir until the oil reservoir pressure reaches a preset value below the cap layer rupture pressure; wherein, a polymer foam stabilizer is added into the sulfonate foaming solution; the set value is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value.
Specifically, a sulfonate foaming solution which can resist temperature higher than a preset temperature is injected into the foam oil reservoir, a polymer foam stabilizer is added into the sulfonate foaming solution until the oil reservoir pressure reaches a preset value below the cap layer rupture pressure, and at the moment, the cap layer rupture pressure minus the oil reservoir pressure is equal to the preset value. The set value is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value. The preset temperature is set according to actual needs, for example, set to 100 ℃, and the embodiment of the invention is not limited. The fourth threshold is set according to practical experience, and the embodiment of the present invention is not limited. The specific implementation process of this step is similar to step S205.
The step S301, the step S302, the step S303, and the step S304 are performed to perform injection operation on the foam oil reservoir, and a process of making the oil reservoir pressure reach a preset value below the cap layer rupture pressure is a process adopted in the second injection operation of the foam oil reservoir and each subsequent injection operation.
In each of the above examples, the set value is 2.5MPa or more and 3MPa or less.
In each of the above embodiments, the third threshold value is greater than 1.5MPa and equal to or less than 2 MPa.
In each of the above embodiments, the fourth threshold value is greater than 1MPa and equal to or less than 1.5 MPa.
Further to the above embodiments, the gas includes at least one of nitrogen, carbon dioxide, methane, ethane, propane, and butane.
In addition to the above embodiments, the solvent may further include at least one of a saturated hydrocarbon having 5 to 10 carbon atoms, an aromatic hydrocarbon having 6 to 10 carbon atoms, an alcohol, and an ether solvent.
In addition to the above embodiments, the pore volume multiple of each slug is equal and is 0.02-0.05 PV.
In addition to the above embodiments, the concentration of the acid solution slug is 5% to 20%. The acid solution is preferably hydrochloric acid, acetic acid, nitric acid, hydrofluoric acid, or oxalic acid.
In addition to the above examples, the concentration of the carbonate solution slug is 5% to 20%. The carbonate is preferably sodium carbonate, sodium bicarbonate or potassium carbonate.
On the basis of the above embodiments, the concentration of the organic amine solution is further 5% to 30%. The organic amine solution is preferably diethylenetriamine or pentamethyldiethylenetriamine; hexamethylenetetramine; bis (hexamethylene) triamine; 1,3, 5-benzenetriamine; at least one of diethylenetriamine, triethylenetetramine, tetraethylenepentamine, bis (hexamethylene) triamine, polylysine, polyimine, dipropylenetriamine, tripropylenetetramine and bis (hexamethylene) triamine.
In addition to the above examples, the concentration of the ammonium salt solution is 5% to 30%. The ammonium salt solution is at least one of carbamide, ammonium carbonate or ammonium chloride.
On the basis of the above embodiments, further, the concentration of the sulfonate is 1% to 3%; the concentration of the foam stabilizer is 0.1-1%; the type of the foam stabilizer is at least one of polyacrylamide with the molecular weight of 100-2500 ten thousand, silicon dioxide with the molecular weight of 20-100 nm or xanthan gum.
On the basis of the above embodiments, further, the surface temperature of a heater used for heating the foam oil reservoir is 5-20 ℃ lower than the coking temperature of crude oil.
In addition to the above examples, the number of days of soaking was 3 to 10 days.
On the basis of the above embodiments, further, the preset value is greater than or equal to 0.5MPa and less than or equal to 1 MPa.
Fig. 4 is a schematic diagram of downhole fluid distribution of a bubble oil reservoir according to a fourth embodiment of the present invention, where the downhole fluid distribution shown in fig. 4 can be obtained by a crude oil exploitation method of the bubble oil reservoir according to the fourth embodiment of the present invention, where 1 is a horizontal well, a heating cable 2 is disposed in the horizontal well 1 to heat the bubble oil reservoir, 3 is a gas slug, 4 is a micro-crack and an earthworm hole, 5 is a pre-solvent slug, 6 is a gas production solution slug, the gas production solution is an acid solution-a carbonate solution-an acid solution-a carbonate solution, an organic amine or an ammonium salt solution, and 7 is a foaming solution slug.
The following is a description of several specific examples of the implementation of the method for extracting crude oil from a foam oil reservoir according to the present invention.
The target heavy oil reservoir a had the following conditions:
(1) the original oil reservoir containing gas and the residual dissolved gas-oil ratio of the oil layer before the scheme of the invention is implemented is 6m3/m3；
(2) The oil layer thickness is 6m, the oil saturation is 70%, the porosity is 32%, and the permeability is 2 darcy;
(3) horizontal well development is adopted, and the length of a horizontal section is 500 m.
The target heavy oil reservoir A meets the applicable conditions of the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention.
The crude oil extraction method for the foam oil reservoir provided by the embodiment of the invention comprises the following steps of:
first round of mining
Firstly, injecting N into a target heavy oil reservoir A from a horizontal well mouth of the target heavy oil reservoir A2Until the oil layer pressure reaches 3MPa below the cap layer rupture pressure, opening the micro cracks of the oil layer of the target heavy oil reservoir A;
secondly, injecting a suspension solution of a heat-conducting filler into the earthworm holes and the microcracks in the target heavy oil reservoir A until the oil reservoir pressure reaches 2MPa below the cap layer rupture pressure so as to increase the heat-conducting capacity of the target heavy oil reservoir A; wherein the heat-conducting filler is aluminum oxide, the particle size of the aluminum oxide is 20 meshes, and the concentration of the aluminum oxide in the suspension solution is 5%; the alumina is carried by a polymer solution, the concentration of the polymer in the polymer solution is 0.1 percent, and the type of the polymer in the polymer solution is polyacrylamide with the molecular weight of 100 ten thousand;
thirdly, injecting a preposed solvent slug into the target heavy oil reservoir A until the oil reservoir pressure reaches 1.5MPa below the cap layer rupture pressure; wherein the preposed solvent adopts saturated hydrocarbon pentane with carbon number of 5;
fourthly, sequentially injecting fluid into the target heavy oil reservoir A in a plug mode according to the sequence of acid solution-carbonate solution-acid solution-carbonate solution until the oil reservoir pressure reaches 1.0MPa below the cap layer rupture pressure; wherein, the PV number of each slug is equal and is 0.02 PV; the concentration of the acid solution slug is 5%, and the acid solution adopts hydrochloric acid; the concentration of the carbonate solution slug is 5%, and the carbonate adopts sodium carbonate.
Fifthly, injecting a sulfonate foaming solution with the temperature resistance higher than 100 ℃ into the target heavy oil reservoir A, and adding a polymer foam stabilizer into the sulfonate foaming solution until the oil reservoir pressure reaches 0.5MPa below the cap layer rupture pressure; wherein the concentration of the sulfonate is 1%, the concentration of the polymer foam stabilizer is 0.1%, and the type of the polymer foam stabilizer is polyacrylamide with the molecular weight of 100 ten thousand;
sixthly, after the injection operation of the target heavy oil reservoir A is finished, starting an electric heater to heat the target heavy oil reservoir A, exciting an oil layer to generate gas, wherein the surface temperature of the heater is 5 ℃ lower than the coking temperature of crude oil, and soaking for 3 days;
seventhly, well opening and recovery are carried out, and the daily oil production is controlled to be 20 t/d;
and step eight, stopping production after judging that the daily oil yield is less than 2 t/d.
Second and subsequent mining
And from the second round of exploitation, the exploitation process of the target heavy oil reservoir A does not comprise the second step in the first round of exploitation, the first threshold value 3MPa of the first step in the first round of exploitation is changed into 2.5MPa, and other parameters are kept unchanged. The subsequent mining process is the same as the second round of mining.
After the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention is implemented on the target heavy oil reservoir A, statistical data show that the final crude oil recovery rate of the horizontal well of the target heavy oil reservoir A is improved by 17% on the basis of cold recovery and reaches 25%. The crude oil exploitation method for the foam oil reservoir provided by the embodiment of the invention improves the recovery ratio of the target heavy oil reservoir A.
The target heavy oil reservoir B has the following conditions:
(1) the original oil reservoir containing gas and the residual dissolved gas-oil ratio of the oil layer before the scheme of the invention is implemented is 8m3/m3；
(2) The thickness of an oil layer is 10m, the oil saturation is 85%, the porosity is 33%, and the permeability is 3 darcy;
(3) horizontal well development is adopted, and the length of the horizontal segment is larger than 600 m.
The target heavy oil reservoir B meets the applicable conditions of the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention.
The original mining steps of the target heavy oil reservoir A by the crude oil mining method of the foam oil reservoir provided by the embodiment of the invention are as follows:
first round of mining
Injecting methane gas into the oil reservoir from a horizontal well mouth of a target heavy oil reservoir B until the oil layer pressure reaches 3.5MPa below the cover layer fracture pressure, and opening micro cracks of the oil layer of the target heavy oil reservoir B;
secondly, injecting a suspension solution of a heat-conducting filler into the earthworm holes and the microcracks in the target heavy oil reservoir B until the oil reservoir pressure reaches 2.7MPa below the cap layer rupture pressure so as to increase the heat-conducting capacity of the target heavy oil reservoir B; wherein, the heat-conducting filler samples magnesium oxide, the particle size of the magnesium oxide is 50 meshes, and the concentration of the magnesium oxide in the suspension solution is 10 percent; carrying magnesium oxide by using a polymer solution, wherein the concentration of a polymer in the polymer solution is 1%, and the type of the polymer in the polymer solution is polyacrylamide with the molecular weight of 2500 ten thousand;
thirdly, injecting a preposed solvent slug into the target heavy oil reservoir B until the oil reservoir pressure reaches 1.7MPa below the cap layer rupture pressure; wherein the preposed solvent adopts C8 aromatic hydrocarbon xylene;
fourthly, sequentially injecting fluid in a plug mode into the target heavy oil reservoir B according to the sequence of acid solution-carbonate solution-acid solution-carbonate solution, or injecting organic amine or ammonium salt solution into the target heavy oil reservoir B until the oil reservoir pressure reaches 1.2MPa below the cap layer rupture pressure; wherein the PV number of each slug is equal and is 0.03 PV; the concentration of the acid solution slug is 10%, and the acid solution is an acetic acid solution; the concentration of the carbonate solution slug is 10%, and the carbonate adopts sodium bicarbonate;
fifthly, injecting a sulfonate foaming solution with the temperature resistance higher than 100 ℃ into the target heavy oil reservoir B, and adding a polymer foam stabilizer into the sulfonate foaming solution until the oil reservoir pressure reaches 0.7MPa below the cap layer rupture pressure; wherein the concentration of the sulfonate is 2%, the concentration of the polymer foam stabilizer is 0.5%, and the type of the polymer foam stabilizer is polyacrylamide with the molecular weight of 2500 ten thousand;
sixthly, after the injection operation of the target heavy oil reservoir B is finished, starting an electric heater to heat the target heavy oil reservoir B, exciting an oil layer to generate gas, wherein the surface temperature of the heater is 10 ℃ lower than the coking temperature of crude oil, and soaking for 5 days;
seventhly, well opening and recovery are carried out, and the daily oil yield is controlled to be 50 t/d;
and step eight, stopping production when the daily oil yield is less than 3 t/d.
Second and subsequent mining
And from the second round of exploitation, the second step in the first round of exploitation is not included in the exploitation process of the target heavy oil reservoir B, the first threshold value of 3.5MPa in the first step in the first round of exploitation is changed into 2.7MPa, and other parameters are kept unchanged. The subsequent mining process is the same as the second round of mining.
After the crude oil recovery method of the foam oil reservoir provided by the embodiment of the invention is implemented on the target heavy oil reservoir B, statistical data show that the final crude oil recovery rate of the horizontal well of the target heavy oil reservoir B is improved by 16% on the basis of cold recovery and reaches 24%. The crude oil exploitation method for the foam oil reservoir provided by the embodiment of the invention improves the recovery ratio of the target heavy oil reservoir A.
The target heavy oil reservoir C has the following conditions:
(1) the original oil reservoir containing gas and the residual dissolved gas-oil ratio of the oil reservoir before the scheme of the invention is implemented is 10m3/m3；
(2) The thickness of an oil layer is 10m, the oil saturation is 83%, the porosity is 33%, and the permeability is 5 darcy;
(3) horizontal well development is adopted, and the length of the horizontal segment is 800 m.
The target heavy oil reservoir C meets the applicable conditions of the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention.
The crude oil extraction method for the foam oil reservoir provided by the embodiment of the invention comprises the following steps of:
first round of mining
Injecting propane gas into the oil reservoir from a horizontal well mouth of a target heavy oil reservoir C until the oil layer pressure reaches 4MPa below the cover layer rupture pressure, and opening micro cracks of the oil layer of the target heavy oil reservoir C;
secondly, injecting a suspension solution of a heat-conducting filler into the earthworm holes and the microcracks in the target heavy oil reservoir C until the reservoir pressure reaches 3MPa below the cap layer rupture pressure so as to increase the heat-conducting capacity of the target heavy oil reservoir C; the heat-conducting filler is aluminum nitride, the particle size of the aluminum nitride is 100 meshes, and the concentration of the aluminum nitride in the suspension solution is 20%; the aluminum nitride is carried by a polymer solution, the concentration of the polymer in the polymer solution is 2 percent, and the polymer type in the polymer solution is silicon dioxide with the molecular weight of 20 nm;
thirdly, injecting a preposed solvent slug into the target heavy oil reservoir C until the oil reservoir pressure reaches 2MPa below the cap layer rupture pressure; wherein the preposed solvent adopts dimethyl ether;
fourthly, adding organic amine solution into the target heavy oil reservoir C until the oil reservoir pressure reaches 1.5MPa below the cap layer rupture pressure; wherein the PV number of each slug is equal and is 0.05 PV; the concentration of the organic amine solution is 5%, and the organic amine adopts diethylenetriamine;
fifthly, injecting a sulfonate foaming solution with temperature resistance higher than 100 ℃ into the target heavy oil reservoir C, and adding a polymer foam stabilizer into the sulfonate foaming solution until the oil reservoir pressure reaches 1MPa below the cap layer rupture pressure; wherein the concentration of the sulfonate is 3%, the concentration of the polymer foam stabilizer is 1%, and the type of the polymer foam stabilizer is silicon dioxide;
sixthly, after the injection operation of the target heavy oil reservoir C is finished, starting an electric heater to heat the target heavy oil reservoir C, exciting an oil layer to generate gas, wherein the surface temperature of the heater is lower than the coking temperature of crude oil by 20 ℃, and soaking for 10 days;
seventhly, well opening and recovery are carried out, and the daily oil production is controlled to be 80 t/d;
and step eight, stopping production after judging that the daily oil yield is less than 4 t/d.
Second and subsequent mining
And from the second round of exploitation, the exploitation process of the target heavy oil reservoir C does not comprise the second step in the first round of exploitation, the first threshold value 4MPa of the first step in the first round of exploitation is changed into 3MPa, and other parameters are kept unchanged. The subsequent mining process is the same as the second round of mining.
After the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention is implemented on the target heavy oil reservoir C, statistical data show that the final crude oil recovery rate of the horizontal well of the target heavy oil reservoir C is improved by 15% on the basis of cold recovery and reaches 24%. The crude oil exploitation method for the foam oil reservoir provided by the embodiment of the invention improves the recovery ratio of the target heavy oil reservoir C.
The target heavy oil reservoir D has the following conditions:
(1) the original oil reservoir containing gas and the residual dissolved gas-oil ratio of the oil layer before the scheme of the invention is implemented is 12m3/m3；
(2) The oil layer thickness is 12m, the oil saturation is 78%, the porosity is 33%, and the permeability is 5 darcy;
(3) horizontal well development is adopted, and the length of a horizontal section is 1200 m.
The target heavy oil reservoir D meets the applicable conditions of the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention.
The crude oil extraction method for the foam oil reservoir provided by the embodiment of the invention comprises the following steps of:
first round of mining
Injecting carbon dioxide gas into the oil reservoir from a horizontal wellhead of the target heavy oil reservoir D until the oil reservoir pressure reaches 4MPa below the cap layer rupture pressure, and opening the micro-cracks of the oil reservoir of the target heavy oil reservoir D;
secondly, injecting a suspension solution of a heat-conducting filler into the earthworm holes and the microcracks in the target heavy oil reservoir D until the oil reservoir pressure reaches 3MPa below the cap layer rupture pressure so as to increase the heat-conducting capacity of the target heavy oil reservoir D; the heat-conducting filler is silicon carbide, the particle size of the silicon carbide is 200 meshes, and the concentration of the silicon carbide in the suspension solution is 30%; carrying silicon carbide by using a polymer solution, wherein the concentration of a polymer in the polymer solution is 3 percent, and the type of the polymer in the polymer solution is xanthan gum with the molecular weight;
thirdly, injecting a preposed solvent slug into the target heavy oil reservoir D until the oil reservoir pressure reaches 2MPa below the cap layer rupture pressure; wherein the pre-solvent comprises at least one of saturated hydrocarbon with carbon number of 5-10, aromatic hydrocarbon with carbon number of 6-10, alcohol and ether solvent;
fourthly, adding an ammonium salt solution into the target heavy oil reservoir D until the oil reservoir pressure reaches 1.5MPa below the cap layer rupture pressure; wherein the PV number of each slug is equal and is 0.05 PV; the concentration of the ammonium salt solution is 30%, and the ammonium salt adopts carbamide;
fifthly, injecting a sulfonate foaming solution with the temperature resistance higher than 100 ℃ into the target heavy oil reservoir D, and adding a polymer foam stabilizer into the sulfonate foaming solution until the oil reservoir pressure reaches 1MPa below the cap layer rupture pressure; wherein the concentration of the sulfonate is 3%, the concentration of the polymer foam stabilizer is 1%, and the type of the polymer foam stabilizer is xanthan gum;
sixthly, after the injection operation of the target heavy oil reservoir D is finished, starting an electric heater to heat the target heavy oil reservoir D, exciting an oil layer to generate gas, wherein the surface temperature of the heater is lower than the coking temperature of crude oil by 20 ℃, and soaking for 10 days;
seventhly, well opening and recovery are carried out, and the daily oil production is controlled to be 100 t/d;
and step eight, stopping production after judging that the daily oil yield is less than 5 t/d.
Second and subsequent mining
And from the second round of exploitation, the exploitation process of the target heavy oil reservoir D does not comprise the second step in the first round of exploitation, the first threshold value 4MPa of the first step in the first round of exploitation is changed into 3MPa, and other parameters are kept unchanged. The subsequent mining process is the same as the second round of mining.
After the crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention is implemented on the target heavy oil reservoir D, statistical data show that the final crude oil recovery rate of the horizontal well of the target heavy oil reservoir D is improved by 19% on the basis of cold recovery and reaches 24%. The crude oil exploitation method of the foam oil reservoir provided by the embodiment of the invention improves the recovery ratio of the target heavy oil reservoir D.
In the description herein, reference to the description of the terms "one embodiment," "a particular embodiment," "some embodiments," "for example," "an example," "a particular example," or "some examples," etc., means that a particular feature, structure, material, or characteristic described in connection with the embodiment or example is included in at least one embodiment or example of the invention. In this specification, the schematic representations of the terms used above do not necessarily refer to the same embodiment or example. Furthermore, the particular features, structures, materials, or characteristics described may be combined in any suitable manner in any one or more embodiments or examples.
The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only exemplary embodiments of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalent substitutions, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.
Claims (24)
1. A method for extracting crude oil from a foam oil reservoir, comprising:
injecting the foam oil reservoir to make the oil reservoir pressure reach a preset value below the cap layer rupture pressure;
heating the foam oil reservoir to excite the oil layer to generate gas and soak the well;
and (5) well recovery is carried out and the daily oil production is controlled within a preset range.
2. The method of claim 1, wherein the injecting the foam reservoir to achieve a reservoir pressure below a cap fracture pressure comprises:
injecting gas into the foam reservoir from a horizontal wellhead until the reservoir pressure reaches a first threshold below a cap layer fracture pressure;
injecting a suspension solution with heat-conducting fillers into the earthworm holes and the microcracks of the foam oil reservoir until the reservoir pressure reaches a second threshold value below the cap layer rupture pressure;
injecting a pre-solvent slug into the foam reservoir until the reservoir pressure reaches a third threshold below cap layer rupture pressure;
sequentially injecting fluid into the foam oil reservoir in a plug mode according to the sequence of an acid solution, a carbonate solution, an acid solution and a carbonate solution, or injecting a preset solution into the foam oil reservoir until the oil reservoir pressure reaches a fourth threshold value below the cap layer rupture pressure; wherein the preset solution is organic amine or ammonium salt solution;
injecting a sulfonate foaming solution with temperature resistance higher than a preset temperature into the foam oil reservoir until the oil reservoir pressure reaches the preset value below the cap layer rupture pressure; wherein, a polymer foam stabilizer is added into the sulfonate foaming solution;
wherein the first threshold is greater than the second threshold, the second threshold is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value.
3. The method of claim 2, wherein the first threshold is greater than 3MPa and less than or equal to 4 MPa.
4. The method of claim 2, wherein the second threshold unit is greater than 2MPa and equal to or less than 3 MPa.
5. The method of claim 2, wherein the thermally conductive filler is at least one of alumina, magnesia, zinc oxide, aluminum nitride, boron nitride, and silicon carbide.
6. The method of claim 2, wherein the thermally conductive filler has a particle size of greater than 20 mesh and 200 mesh or less.
7. The method according to claim 2, wherein the thermally conductive filler is carried by a polymer solution, and the polymer concentration in the polymer solution is 0.1-3%.
8. The method according to claim 7, wherein the polymer type in the polymer solution is at least one of polyacrylamide having a molecular weight of 100 to 2500 ten thousand, silica having a molecular weight of 20 to 100nm, or xanthan gum.
9. The method of claim 1, wherein the injecting the foam reservoir to achieve a reservoir pressure below a cap fracture pressure comprises:
injecting gas into the foam reservoir from a horizontal wellhead until the reservoir pressure reaches a set value below a cap layer rupture pressure;
injecting a pre-solvent slug into the foam reservoir until the reservoir pressure reaches a third threshold below cap layer rupture pressure;
sequentially injecting fluid into the foam oil reservoir in a plug mode according to the sequence of an acid solution, a carbonate solution, an acid solution and a carbonate solution, or injecting a preset solution into the foam oil reservoir until the oil reservoir pressure reaches a fourth threshold value below the cap layer rupture pressure; wherein the preset solution is organic amine or ammonium salt solution;
injecting a sulfonate foaming solution with temperature resistance higher than a preset temperature into the foam oil reservoir until the oil reservoir pressure reaches a preset value below the cap layer rupture pressure; wherein, a polymer foam stabilizer is added into the sulfonate foaming solution;
the set value is greater than the third threshold, the third threshold is greater than the fourth threshold, and the fourth threshold is greater than the preset value.
10. The method according to claim 9, wherein the set value is 2.5MPa or more and 3MPa or less.
11. Method according to claim 2 or 9, characterized in that said third threshold value is greater than 1.5MPa and less than or equal to 2 MPa.
12. Method according to claim 2 or 9, characterized in that said fourth threshold value is greater than 1MPa and equal to or less than 1.5 MPa.
13. The method of claim 2 or 9, wherein the gas comprises at least one of nitrogen, carbon dioxide, methane, ethane, propane, and butane.
14. The method according to claim 2 or 9, wherein the solvent includes at least one of a saturated hydrocarbon having 5 to 10 carbon atoms, an aromatic hydrocarbon having 6 to 10 carbon atoms, an alcohol, and an ether solvent.
15. The method of claim 2 or 9, wherein the pore volume multiple of each slug is equal to 0.02 to 0.05 PV.
16. The method of claim 2 or 9, wherein the acid solution slug is at a concentration of 5% to 20%.
17. The method according to claim 2 or 9, wherein the concentration of the carbonate solution slug is between 5% and 20%.
18. Method according to claim 2 or 9, characterized in that the concentration of the organic amine solution is 5-30%.
19. The method according to claim 2 or 9, wherein the concentration of the ammonium salt solution is 5% to 30%.
20. The method according to claim 2 or 9, characterized in that the sulfonate concentration is 1% to 3%; the concentration of the foam stabilizer is 0.1-1%; the type of the foam stabilizer is at least one of polyacrylamide with the molecular weight of 100-2500 ten thousand, silicon dioxide with the molecular weight of 20-100 nm or xanthan gum.
21. The method according to claim 1, wherein the surface temperature of a heater used for heating the foam oil reservoir is 5-20 ℃ lower than the coking temperature of the crude oil.
22. The method of claim 1, wherein the number of days of soaking is 3 to 10 days.
23. The method according to claim 1, wherein the preset value is greater than or equal to 0.5MPa and less than or equal to 1 MPa.
24. The method of claim 1, further comprising:
and stopping production if the daily oil yield is judged to be less than the oil yield threshold value.
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