CN111058824B - Temporary plugging and shunting acidification method for strong heterogeneous sandstone reservoir through sieve tube - Google Patents
Temporary plugging and shunting acidification method for strong heterogeneous sandstone reservoir through sieve tube Download PDFInfo
- Publication number
- CN111058824B CN111058824B CN201911337544.6A CN201911337544A CN111058824B CN 111058824 B CN111058824 B CN 111058824B CN 201911337544 A CN201911337544 A CN 201911337544A CN 111058824 B CN111058824 B CN 111058824B
- Authority
- CN
- China
- Prior art keywords
- acidizing
- fluid
- temporary plugging
- well
- sandstone reservoir
- 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 40
- 230000020477 pH reduction Effects 0.000 title abstract description 22
- 239000012530 fluid Substances 0.000 claims abstract description 58
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 48
- -1 iron ion Chemical class 0.000 claims abstract description 20
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 18
- 230000007797 corrosion Effects 0.000 claims abstract description 16
- 238000005260 corrosion Methods 0.000 claims abstract description 16
- 239000003112 inhibitor Substances 0.000 claims abstract description 16
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims abstract description 16
- 229910052742 iron Inorganic materials 0.000 claims abstract description 16
- 239000003381 stabilizer Substances 0.000 claims abstract description 16
- 230000002579 anti-swelling effect Effects 0.000 claims abstract description 15
- 238000004519 manufacturing process Methods 0.000 claims abstract description 14
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims abstract description 12
- 239000000654 additive Substances 0.000 claims abstract description 10
- 230000000996 additive effect Effects 0.000 claims abstract description 10
- 238000006073 displacement reaction Methods 0.000 claims abstract description 9
- 125000006850 spacer group Chemical group 0.000 claims abstract description 9
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims abstract description 8
- CSCPPACGZOOCGX-UHFFFAOYSA-N Acetone Chemical compound CC(C)=O CSCPPACGZOOCGX-UHFFFAOYSA-N 0.000 claims abstract description 8
- MSWZFWKMSRAUBD-UHFFFAOYSA-N beta-D-galactosamine Natural products NC1C(O)OC(CO)C(O)C1O MSWZFWKMSRAUBD-UHFFFAOYSA-N 0.000 claims abstract description 8
- MSWZFWKMSRAUBD-QZABAPFNSA-N beta-D-glucosamine Chemical compound N[C@H]1[C@H](O)O[C@H](CO)[C@@H](O)[C@@H]1O MSWZFWKMSRAUBD-QZABAPFNSA-N 0.000 claims abstract description 8
- 229960000583 acetic acid Drugs 0.000 claims abstract description 4
- NNTOJPXOCKCMKR-UHFFFAOYSA-N boron;pyridine Chemical compound [B].C1=CC=NC=C1 NNTOJPXOCKCMKR-UHFFFAOYSA-N 0.000 claims abstract description 4
- 239000012362 glacial acetic acid Substances 0.000 claims abstract description 4
- 239000007788 liquid Substances 0.000 claims description 16
- FKNQCJSGGFJEIZ-UHFFFAOYSA-N 4-methylpyridine Chemical compound CC1=CC=NC=C1 FKNQCJSGGFJEIZ-UHFFFAOYSA-N 0.000 claims description 10
- 238000002347 injection Methods 0.000 claims description 9
- 239000007924 injection Substances 0.000 claims description 9
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 8
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 8
- RTZKZFJDLAIYFH-UHFFFAOYSA-N ether Substances CCOCC RTZKZFJDLAIYFH-UHFFFAOYSA-N 0.000 claims description 7
- 229920002503 polyoxyethylene-polyoxypropylene Polymers 0.000 claims description 6
- 125000002091 cationic group Chemical group 0.000 claims description 5
- BEGBSFPALGFMJI-UHFFFAOYSA-N ethene;sodium Chemical group [Na].C=C BEGBSFPALGFMJI-UHFFFAOYSA-N 0.000 claims description 5
- 229920002401 polyacrylamide Polymers 0.000 claims description 5
- 235000019270 ammonium chloride Nutrition 0.000 claims description 4
- 239000011148 porous material Substances 0.000 claims description 4
- 239000001103 potassium chloride Substances 0.000 claims description 4
- 235000011164 potassium chloride Nutrition 0.000 claims description 4
- 125000003047 N-acetyl group Chemical group 0.000 claims description 3
- KJPRLNWUNMBNBZ-QPJJXVBHSA-N (E)-cinnamaldehyde Chemical compound O=C\C=C\C1=CC=CC=C1 KJPRLNWUNMBNBZ-QPJJXVBHSA-N 0.000 claims description 2
- DBAMUTGXJAWDEA-UHFFFAOYSA-N Butynol Chemical compound CCC#CO DBAMUTGXJAWDEA-UHFFFAOYSA-N 0.000 claims description 2
- 239000004721 Polyphenylene oxide Substances 0.000 claims description 2
- 229920000289 Polyquaternium Polymers 0.000 claims description 2
- 239000007864 aqueous solution Substances 0.000 claims description 2
- 229940117916 cinnamic aldehyde Drugs 0.000 claims description 2
- KJPRLNWUNMBNBZ-UHFFFAOYSA-N cinnamic aldehyde Natural products O=CC=CC1=CC=CC=C1 KJPRLNWUNMBNBZ-UHFFFAOYSA-N 0.000 claims description 2
- MGFYIUFZLHCRTH-UHFFFAOYSA-N nitrilotriacetic acid Chemical compound OC(=O)CN(CC(O)=O)CC(O)=O MGFYIUFZLHCRTH-UHFFFAOYSA-N 0.000 claims description 2
- 229920000570 polyether Polymers 0.000 claims description 2
- TVDSBUOJIPERQY-UHFFFAOYSA-N prop-2-yn-1-ol Chemical compound OCC#C TVDSBUOJIPERQY-UHFFFAOYSA-N 0.000 claims description 2
- 239000011734 sodium Substances 0.000 claims description 2
- 229910052708 sodium Inorganic materials 0.000 claims description 2
- 230000002265 prevention Effects 0.000 claims 1
- 230000008961 swelling Effects 0.000 claims 1
- 238000010276 construction Methods 0.000 abstract description 12
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 abstract description 11
- 230000008569 process Effects 0.000 abstract description 10
- 230000000694 effects Effects 0.000 abstract description 8
- IXCSERBJSXMMFS-UHFFFAOYSA-N hydrogen chloride Substances Cl.Cl IXCSERBJSXMMFS-UHFFFAOYSA-N 0.000 abstract 1
- 239000002253 acid Substances 0.000 description 10
- 239000000499 gel Substances 0.000 description 8
- 230000035699 permeability Effects 0.000 description 5
- 239000007787 solid Substances 0.000 description 5
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 description 4
- 238000002955 isolation Methods 0.000 description 4
- 239000004576 sand Substances 0.000 description 4
- 230000000903 blocking effect Effects 0.000 description 3
- GLDOVTGHNKAZLK-UHFFFAOYSA-N n-octadecyl alcohol Natural products CCCCCCCCCCCCCCCCCCO GLDOVTGHNKAZLK-UHFFFAOYSA-N 0.000 description 3
- LCPVQAHEFVXVKT-UHFFFAOYSA-N 2-(2,4-difluorophenoxy)pyridin-3-amine Chemical compound NC1=CC=CN=C1OC1=CC=C(F)C=C1F LCPVQAHEFVXVKT-UHFFFAOYSA-N 0.000 description 2
- 229910001870 ammonium persulfate Inorganic materials 0.000 description 2
- 230000015572 biosynthetic process Effects 0.000 description 2
- 235000015110 jellies Nutrition 0.000 description 2
- 239000008274 jelly 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
- 238000001556 precipitation Methods 0.000 description 2
- JQWHASGSAFIOCM-UHFFFAOYSA-M sodium periodate Chemical compound [Na+].[O-]I(=O)(=O)=O JQWHASGSAFIOCM-UHFFFAOYSA-M 0.000 description 2
- CHQMHPLRPQMAMX-UHFFFAOYSA-L sodium persulfate Substances [Na+].[Na+].[O-]S(=O)(=O)OOS([O-])(=O)=O CHQMHPLRPQMAMX-UHFFFAOYSA-L 0.000 description 2
- 230000000638 stimulation Effects 0.000 description 2
- MLIWQXBKMZNZNF-KUHOPJCQSA-N (2e)-2,6-bis[(4-azidophenyl)methylidene]-4-methylcyclohexan-1-one Chemical compound O=C1\C(=C\C=2C=CC(=CC=2)N=[N+]=[N-])CC(C)CC1=CC1=CC=C(N=[N+]=[N-])C=C1 MLIWQXBKMZNZNF-KUHOPJCQSA-N 0.000 description 1
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 1
- 150000008055 alkyl aryl sulfonates Chemical class 0.000 description 1
- 125000000217 alkyl group Chemical group 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 229910001748 carbonate mineral Inorganic materials 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000000151 deposition Methods 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000000835 fiber Substances 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- USHAGKDGDHPEEY-UHFFFAOYSA-L potassium persulfate Chemical compound [K+].[K+].[O-]S(=O)(=O)OOS([O-])(=O)=O USHAGKDGDHPEEY-UHFFFAOYSA-L 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 238000012216 screening Methods 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- BDHFUVZGWQCTTF-UHFFFAOYSA-M sulfonate Chemical compound [O-]S(=O)=O BDHFUVZGWQCTTF-UHFFFAOYSA-M 0.000 description 1
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
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
- C09K8/504—Compositions based on water or polar solvents
- C09K8/506—Compositions based on water or polar solvents containing organic compounds
-
- 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
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
-
- 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/72—Eroding chemicals, e.g. acids
- C09K8/74—Eroding chemicals, e.g. acids combined with additives added for specific purposes
-
- 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
-
- 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
- E21B43/02—Subsoil filtering
- E21B43/08—Screens or liners
- E21B43/086—Screens with preformed openings, e.g. slotted liners
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Physics & Mathematics (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Dispersion Chemistry (AREA)
- Preventing Corrosion Or Incrustation Of Metals (AREA)
Abstract
The invention discloses a temporary plugging and shunting acidizing method for a strong heterogeneous sandstone reservoir through a sieve tube, which mainly comprises the steps of sequentially injecting an acidizing spacer fluid A, an acidizing fluid B, a temporary plugging agent C, an acidizing fluid B, a post fluid D and a displacement fluid E into a shaft, closing the shaft for a period of time, determining whether to perform flowback according to the type of the shaft, and then opening the shaft for production. Wherein, the acidification spacer fluid A consists of the following components: HCl, corrosion inhibitor, iron ion stabilizer, anti-swelling agent, demulsifier and the balance of water; the acidizing fluid B consists of the following components: HCl, HF or HBF 4 Corrosion inhibitor, iron ion stabilizer, anti-swelling agent, demulsifier, cleanup additive and the balance of water; the temporary plugging agent C consists of the following components: d-glucosamine, glacial acetic acid, pyridine-borane complex, acetone, methanol, HCl and the balance of water. The method has the advantages of simple construction process, low cost and high temporary plugging strength, and can achieve ideal temporary plugging and shunting effects in high-permeability extremely-poor and high-heterogeneity sandstone reservoirs.
Description
Technical Field
The invention relates to the technical field of acidification production increase of oil exploitation reservoirs, in particular to a temporary plugging and shunting acidification method for a strong heterogeneous sandstone reservoir through a sieve tube.
Background
Sandstone oil and gas reservoirs are an important component of oil and gas resources in the world and account for about 57 percent of the conventional oil and gas resources in the world. During the well construction process, the filtration loss of drilling completion fluid causes certain pollution to a production well and an injection well, and the skin coefficient is positive, so that the production or injection is usually carried out after acidification in an oil field. In addition, most sandstone reservoirs are strong heterogeneity, the permeability of each well section is very poor, if acid liquor is directly injected, most acid liquor directly flows into a high permeable layer based on the principle of minimum flow resistance, and a low permeable layer is not effectively acidized and modified, so that the whole well section can be uniformly acidized by using a temporary plugging agent. For a sandstone reservoir with loose cementation, a sand control completion process is often adopted, the most common sand control process is screen pipe completion, for sand control, the diameter of holes on the wall of a screen pipe is dozens of micrometers to hundreds of micrometers, and if a conventional solid temporary plugging agent such as particles, fibers and the like is adopted, the solid temporary plugging agent is difficult to reach the reservoir through the screen pipe and acid liquor shunting cannot be realized, so the temporary plugging agent is required to be liquid firstly, and becomes jelly or solid in the reservoir after passing through the screen pipe, and the acid liquor shunting is realized temporarily. Aiming at the special temporary plugging agent, a special construction process is required, so that a sandstone reservoir screen pipe passing temporary plugging diversion acidification method is very necessary.
At present, documents related to reservoir screening pipe diversion acidification are few, and a self-steering diversion acidification method for a sandstone reservoir disclosed in patent CN201610513187.4 realizes temporary blocking diversion by means of the change of self viscosity of diversion acid, wherein the viscosity of the self-steering diversion acidification method is from dozens of millipascal seconds to hundreds of millipascal seconds, the temporary blocking strength is very limited, and the self-steering diversion acidification method is suitable for reservoirs with extremely low permeability differences. For strong heterogeneous reservoirs, because the permeability of the reservoir is very poor, if diverting acid is still used, the diverting effect is very unsatisfactory according to the field application condition, and the expected design target is difficult to achieve. Patent CN201910701577.8 discloses a diversion flow-splitting acidification method for a long well section of a hypertonic sandstone reservoir, which provides a profile control agent B and a phase-change plugging agent C, wherein jelly is formed by relying on the profile control agent B, and then a solid-phase particle plugging agent is formed by relying on the phase-change plugging agent C.
Based on the situation, the invention provides the temporary plugging and shunting acidification method for the strong heterogeneous sandstone reservoir through the sieve tube, and the method has the advantages of simple construction process and low cost.
Disclosure of Invention
The invention aims to provide a temporary plugging and shunting acidification method for a strong heterogeneous sandstone reservoir through a sieve tube, aiming at the defects of a reservoir sieve tube shunting acidification technology in the prior art.
The invention provides a temporary plugging and shunting acidification method for a strong heterogeneous sandstone reservoir through a sieve tube, which comprises the following specific steps of:
s1, injecting an acidizing spacer fluid A into the shaft, wherein the acidizing spacer fluid A comprises the following components in percentage by weight: 3-15% of HCl, 0.1-0.6% of corrosion inhibitor, 1-2% of iron ion stabilizer, 1-2% of anti-swelling agent, 0.1-0.6% of demulsifier and the balance of water. The acidizing isolation fluid A mainly has the functions of reacting with carbonate minerals in the sandstone reservoir and isolating formation fluid from the acidizing fluid B, so that secondary precipitation generated by the acidizing fluid B during formation treatment is reduced.
S2, injecting an acidizing fluid B into the well bore, wherein the acidizing fluid B comprises the following components in percentage by weight: 6-15% HCl, 1-3% HF or 4-8% HBF 4 0.5-1.2% of corrosion inhibitor, 1-2% of iron ion stabilizer, 1-2% of anti-swelling agent, 0.1-0.6% of demulsifier, 0.1-0.6% of cleanup additive and the balance of water. The acidizing fluid B mainly has the effects of reacting with a sandstone reservoir matrix and hydrochloric acid insoluble plugs and improving the permeability of the reservoir.
S3, injecting a temporary plugging agent C into the shaft, wherein the temporary plugging agent C comprises the following components in percentage by weight: 2.1% D-glucosamine, 0.7% glacial acetic acid, 1.7% pyridine-borane complex, 2.3% acetone, 8.2% methanol, 0.9% HCl, the balance water; wherein the D-glucosamine is D-glucosamine with randomly distributed N-acetyl on beta-1 to 4 chains. The temporary plugging agent C is liquid at first, can smoothly pass through a sieve tube with any size, and has good injectability. The temporary plugging agent C mainly has the effect that the temporary plugging agent C smoothly passes through the sieve tube firstly, flows into the area treated by the acid liquor in the previous step based on the principle of minimum flow resistance, and is changed from liquid sol into solid gel under the stimulation of pH and temperature to form a temporary plugging layer with higher plugging strength. And (3) injecting an acidizing fluid B next step, wherein the acidizing fluid B flows to a low-permeability area which is not treated before on the basis of the principle of minimum flow resistance due to the blocking of the temporary plugging agent C, so that acid liquor shunting is realized.
S4, injecting acidizing fluid B into the well bore again;
s5, injecting a post fluid D into the well bore, wherein the post fluid D comprises the following components in percentage by weight: 5-12% of HCl, 2-3% of a gel breaker, 0.1-0.6% of a corrosion inhibitor, 1-2% of an iron ion stabilizer, 1-2% of an anti-swelling agent, 1-2% of a cleanup additive and the balance of water. The post-fluid D is mainly used for driving the acidizing fluid B near the shaft into the deep part of a reservoir, so that secondary precipitation possibly generated in residual acid is prevented from depositing near the shaft, and in addition, the most important is to inject the gel breaker into the reservoir, so that the solid gel formed in the early stage is broken, and the gel is conveniently drained back.
And S6, injecting the displacement fluid E into the well bore. The displacement fluid E primarily functions to displace the post fluid D in the wellbore into the reservoir.
And S7, closing the well for a period of time, determining whether to flow back or not according to the well type within the range of 60-100min, and then opening the well for production. If the well is an injection well, flowback is not needed, and the well can be directly opened for water injection; if the well is a production well, the well needs to be drained again and then the well is opened for production.
Preferably, in the above method, the amount of the acidified isolation solution A is 0.5m 3 /m～1.2m 3 The dosage of the acidizing fluid B is 1.6m 3 /m～2.8m 3 The dosage of the temporary plugging agent C is 1-2 times of the pore volume of the designed plugging removal radius, and the dosage of the postposition liquid D is 0.6m 3 /m～1.2m 3 And m, the using amount of the displacement liquid E is 1.1-2.5 times of the volume of the oil pipe.
Preferably, during specific construction, if the amount of the acidizing fluid B is designed to be large, the amount is generally more than 60m 3 Repeating the steps S3-S4, wherein the amount of the temporary plugging agent C and the acidizing fluid B injected in a single time is 0.2-0.4 times of the volume of the designed dosage, and repeatedly and alternately injecting the temporary plugging agent C and the acidizing fluid B until the designed acidizing fluid B is injected. The alternate injection can improve the acidification effect to a certain extent, but if the designed amount of the acidification liquid B is small, the construction procedure is complicated if the alternate injection is carried out, and the acidification effect is not obviously improved. In addition, in order to simplify the construction process, steps S3 and S4 may not be repeated, which is not obvious, although it has an effect.
Preferably, the displacement fluid E is an aqueous solution of ammonium chloride or potassium chloride, and the mass percentage concentration of the ammonium chloride or the potassium chloride is 2%.
Preferably, the corrosion inhibitor is one of 4-methylpyridine, propiolic alcohol, butynol, cinnamaldehyde and alpha-alkenylbenzophenone. The iron ion stabilizer is one of nitrilotriacetic acid and sodium ethylene diamine tetracetate. The anti-swelling agent is one of cationic polyacrylamide and polyquaternium. The demulsifier is one of alkyl sodium sulfonate, polyoxyethylene polyoxypropylene octadecanol ether and polyoxyethylene polyoxypropylene polyether. The cleanup additive is one of alkyl aryl sulfonate and ethyl alkyl aldehyde oxide. The gel breaker is at least one of ammonium persulfate, sodium persulfate, potassium persulfate, sodium periodate and potassium periodate.
Compared with the prior art, the invention has the advantages that:
(1) compared with diverting acid, the temporary plugging agent has high temporary plugging strength and can achieve ideal temporary plugging and shunting effects in high-permeability extremely poor and high-heterogeneity sandstone reservoirs. The method has simple construction process and low cost.
(2) The temporary plugging agent with temperature and pH stimulation response provided by the invention can realize temporary plugging only by one construction procedure, and has the advantages of simple construction process and low cost.
(3) The temporary plugging agent provided by the invention is liquid at first, can smoothly pass through sieve pipes of any size, and has good injectivity.
Additional advantages, objects, and features of the invention will be set forth in part in the description which follows and in part will become apparent to those having ordinary skill in the art upon examination of the following or may be learned from practice of the invention.
Drawings
Fig. 1 is a flow chart of the temporary plugging and shunt acidizing method of the strong heterogeneous sandstone reservoir by using the sieve tube.
Detailed Description
The preferred embodiments of the present invention will be described in conjunction with the accompanying drawings, and it should be understood that they are presented herein only to illustrate and explain the present invention and not to limit the present invention.
The process flow of the temporary plugging and shunting acidizing method for the strong heterogeneous sandstone reservoir through the sieve tube is shown in figure 1.
Example 1
The X production well of a certain oil field of the Bohai sea is used as an acidification modification object, the modification scheme design is carried out by using the temporary plugging and shunting acidification method of the strong heterogeneous sandstone reservoir through the sieve tube, the target well section is 2438-2527 m, the porosity is 21%, the sand production of the reservoir is realized, the well completion is carried out by using the sieve tube, and the reservoir is completed by using the sieve tubeStrong heterogeneity, great permeability difference, and uneven liquid production section, the designed blockage removal radius is 1.5m, the casing size is 157mm, and the blockage removal radius pore volume is 83.1m 3 The inner diameter of the oil pipe is 62mm, and the volume of the oil pipe is 7.6m 3 。
Preparing an acidizing isolation fluid A, an acidizing fluid B, a temporary plugging agent C, a post fluid D and a displacement fluid E in advance before construction.
The dosage of the acidification isolation liquid A is 0.8m 3 A specific value of 71.2m 3 . The dosage of the acidizing fluid B is 2.1m 3 A value of/m, in particular 174.5m 3 . The dosage of the temporary plugging agent C is 1 time of the pore volume of the designed plugging removal radius, specifically 83.1m 3 . The dosage of the postposition liquid D is 0.9m 3 A specific value of 80.1m 3 . The dosage of the displacing liquid E is 1.5 times of the volume of the oil pipe, and is specifically 11.4m 3 。
Acidifying the spacer fluid A: 15% of HCl, 0.6% of corrosion inhibitor, 2% of iron ion stabilizer, 2% of anti-swelling agent, 0.6% of demulsifier and the balance of water. The corrosion inhibitor is 4-methylpyridine. The iron ion stabilizer is sodium ethylene diamine tetracetate. The anti-swelling agent is cationic polyacrylamide. The demulsifier is polyoxyethylene polyoxypropylene octadecanol ether.
Acidifying liquid B: 15% of HCl, 3% of HF, 1.2% of corrosion inhibitor, 2% of iron ion stabilizer, 2% of anti-swelling agent, 0.6% of demulsifier, 0.6% of cleanup additive and the balance of water. The corrosion inhibitor is 4-methylpyridine. The iron ion stabilizer is sodium ethylene diamine tetracetate. The anti-swelling agent is cationic polyacrylamide. The demulsifier is polyoxyethylene polyoxypropylene octadecanol ether. The cleanup additive is an ethyl alkyl aldehyde oxide.
Temporary plugging agent C: 2.1% D-glucosamine with randomly distributed N-acetyl groups on the beta-1 to 4 chains, 0.7% glacial acetic acid, 1.7% pyridine-borane complex, 2.3% acetone, 8.2% methanol, 0.9% HCl, the remainder being water.
Postliquid D: 8% of HCl, 3% of gel breaker, 0.4% of corrosion inhibitor, 1.8% of iron ion stabilizer, 1.8% of anti-swelling agent, 2% of cleanup additive and the balance of water. The gel breaker consists of 2 percent of ammonium persulfate and 1 percent of sodium persulfate. The corrosion inhibitor is 4-methylpyridine. The iron ion stabilizer is sodium ethylene diamine tetracetate. The anti-swelling agent is cationic polyacrylamide. The cleanup additive is an ethyl alkyl aldehyde oxide.
Displacing liquid E: 2% NH 4 Cl and the balance of water.
The percentage contents of the components are all mass percentages.
The specific construction method comprises the following steps:
step S1: injection 71.2m into the wellbore 3 Acidifying spacer fluid A.
Step S2: injecting 34.9m into the well bore 3 The acidified liquid B of (1).
Step S3: injecting 20.8m into the well bore 3 The temporary plugging agent C.
Step S4: injecting 34.9m into the well bore 3 The acidizing fluid B; and then alternately repeating the steps S3 and S4 until the designed acidizing fluid B is filled, repeating the step S3 for 4 times in total, and repeating the step S4 for 4 times in total.
Step S5: injecting 80.1m into the well bore 3 And (3) postliquid D.
Step S6: injecting 11.4m into the well bore 3 Displacing fluid E from the wellbore into the reservoir.
Step S7: and (4) closing the well for 80 minutes, performing flowback, and after flowback is finished, starting normal production of the X well.
Although the present invention has been described with reference to a preferred embodiment, it should be understood that various changes, substitutions and alterations can be made herein without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (9)
1. A temporary plugging and shunting acidizing method for a strong heterogeneous sandstone reservoir through a sieve tube is characterized by comprising the following steps of:
s1, injecting an acidizing spacer fluid A into the shaft, wherein the acidizing spacer fluid A comprises the following components in percentage by weight: 3-15% of HCl, 0.1-0.6% of corrosion inhibitor, 1-2% of iron ion stabilizer, 1-2% of anti-swelling agent, 0.1-0.6% of demulsifier and the balance of water;
s2, injecting an acidizing fluid B into the well bore, wherein the acidizing fluid B comprises the following components in percentage by weight: 6-15% HCl, 1-3% HF or 4-8% HBF 4 0.5-1.2% of corrosion inhibitor, 1-2% of iron ion stabilizer, 1-2% of anti-swelling agent, 0.1-0.6% of demulsifier, 0.1-0.6% of cleanup additive and the balance of water;
s3, injecting a temporary plugging agent C into the shaft, wherein the temporary plugging agent C comprises the following components in percentage by weight: 2.1% D-glucosamine, 0.7% glacial acetic acid, 1.7% pyridine-borane complex, 2.3% acetone, 8.2% methanol, 0.9% HCl, the balance water; wherein D-glucosamine is D-glucosamine with randomly distributed N-acetyl groups on the beta-1 to 4 chains;
s4, injecting acidizing fluid B into the well bore again;
s5, injecting a post fluid D into the shaft, wherein the post fluid D comprises the following components in percentage by weight: 5-12% of HCl, 2-3% of a gel breaker, 0.1-0.6% of a corrosion inhibitor, 1-2% of an iron ion stabilizer, 1-2% of an anti-swelling agent, 1-2% of a cleanup additive and the balance of water;
s6, injecting displacement fluid E into the well bore;
and S7, closing the well for a period of time, determining whether to flow back according to the well type, and then opening the well for production.
2. The screen-passing temporary plugging and shunt acidizing method for the strong heterogeneous sandstone reservoir of claim 1, wherein in the step S7, the well closing time is 60-100min, and if the well is an injection well, the well can be directly opened for water injection without flowback; if the well is a production well, the well needs to be drained again and then the well is opened for production.
3. The temporary plugging and shunting acidizing method for the sieve tube of the strongly heterogeneous sandstone reservoir as claimed in claim 1, wherein the dosage of the acidizing spacer fluid A is 0.5-1.2 m 3 M, the dosage of the acidizing fluid B is 1.6-2.8 m 3 The dosage of the temporary plugging agent C is 1-2 times of the pore volume of the designed plugging removal radius, and the dosage of the postposition liquid D is0.6～1.2m 3 And m, the using amount of the displacement liquid E is 1.1-2.5 times of the volume of the oil pipe.
4. The method for temporary plugging and shunting acidizing of strongly heterogeneous sandstone reservoir through a sieve tube according to claim 3, wherein the amount of the acidizing fluid B is designed to be larger and larger than 60m 3 If the acidizing fluid B is injected into the shaft again in the step S4, the temporary plugging agent C and the acidizing fluid B are repeatedly and alternately injected by repeating the steps S3-S4 until the designed acidizing fluid B is completely injected.
5. The method for screen pipe plugging and shunt acidizing of a strongly heterogeneous sandstone reservoir of claim 1, wherein the displacement fluid E is an aqueous solution of ammonium chloride or potassium chloride, and the mass percent concentration of the ammonium chloride or potassium chloride is 2%.
6. The method for screen pipe plugging and flow acidizing of a strongly heterogeneous sandstone reservoir of claim 1, wherein the corrosion inhibitor is one of 4-methylpyridine, propiolic alcohol, butynol, cinnamaldehyde and alpha-alkenylbenzophenone.
7. The method for screen pipe plugging and shunt acidizing of a strongly heterogeneous sandstone reservoir of claim 1, wherein the iron ion stabilizer is one of nitrilotriacetic acid and sodium ethylene diamine tetracetate.
8. The method for screen-through temporary plugging and shunt acidizing of a strongly heterogeneous sandstone reservoir of claim 1, wherein the swelling prevention agent is one of cationic polyacrylamide and polyquaternium.
9. The screen-through temporary plugging and shunt acidizing method for the strongly heterogeneous sandstone reservoir of claim 1, wherein the demulsifier is one of sodium alkylsulfonate, polyoxyethylene polyoxypropylene stearyl ether and polyoxyethylene polyoxypropylene polyether.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911337544.6A CN111058824B (en) | 2019-12-23 | 2019-12-23 | Temporary plugging and shunting acidification method for strong heterogeneous sandstone reservoir through sieve tube |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201911337544.6A CN111058824B (en) | 2019-12-23 | 2019-12-23 | Temporary plugging and shunting acidification method for strong heterogeneous sandstone reservoir through sieve tube |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN111058824A CN111058824A (en) | 2020-04-24 |
| CN111058824B true CN111058824B (en) | 2022-09-06 |
Family
ID=70301653
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201911337544.6A Active CN111058824B (en) | 2019-12-23 | 2019-12-23 | Temporary plugging and shunting acidification method for strong heterogeneous sandstone reservoir through sieve tube |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111058824B (en) |
Families Citing this family (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN114893162B (en) * | 2022-03-15 | 2023-07-28 | 中海油能源发展股份有限公司 | Horizontal screen pipe well reservoir transformation process method |
| CN114607341B (en) * | 2022-04-12 | 2023-07-14 | 西南石油大学 | Temporary plugging steering fracturing method and oil gas exploitation method |
| CN115725282B (en) * | 2022-09-13 | 2024-01-26 | 中海石油(中国)有限公司上海分公司 | Composite temporary plugging agent and application thereof |
Family Cites Families (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| DD160779A3 (en) * | 1980-12-18 | 1984-03-07 | Georg Pacholke | METHOD FOR THE SELECTIVE CLEANING OF UNDERGROUND FORMATIONS |
| CN103592213B (en) * | 2013-11-25 | 2015-10-28 | 中国石油化工集团公司 | A kind of adaptation many permeability grade distributary acid experimental provision and evaluation method |
| CN108467724A (en) * | 2018-03-12 | 2018-08-31 | 中国石油天然气股份有限公司 | A kind of online shunting acid and preparation method thereof that water injection well is continuously injected into |
| CN108384528B (en) * | 2018-03-12 | 2020-07-10 | 中国石油天然气股份有限公司 | Diverting agent for diverting and acidifying water injection well and preparation method thereof |
| CN110529084B (en) * | 2019-07-31 | 2021-11-02 | 中国海洋石油集团有限公司 | Long well section steering, shunting and acidizing method for high-permeability sandstone reservoir |
-
2019
- 2019-12-23 CN CN201911337544.6A patent/CN111058824B/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CN111058824A (en) | 2020-04-24 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN111058824B (en) | Temporary plugging and shunting acidification method for strong heterogeneous sandstone reservoir through sieve tube | |
| CN110159243B (en) | Acid fracturing method for seam network of carbonate rock reservoir | |
| CN105952430A (en) | Volume fracturing and energy replenishing method for low-yield horizontal well in dense oil reservoir | |
| CN107366530B (en) | Deep shale gas reservoir yield increasing method and application thereof | |
| CN106014330B (en) | A method of improving leakage casing damaged well chemical plugging success rate | |
| CN106567702A (en) | Method for improving complexity index of deep shale gas fracture | |
| CN110656920B (en) | Acid fracturing method for complex fractures in carbonate reservoir | |
| RU2456439C1 (en) | Method for balancing injection well water-intake capacity profile and restriction of water influx to production wells | |
| CN106894802B (en) | Small-sized fracturing testing method suitable for shale gas well | |
| CN112302612A (en) | Functional slickwater temporary blocking and steering volume fracturing method for synchronously implanting oil displacement agent | |
| CN106567701A (en) | Hydraulic fracturing method | |
| CN106958438B (en) | A kind of method for removing blockage of polymer flooding blocking well | |
| CN105756649B (en) | A kind of method of hyposmosis Waxy Production Wells volume increase | |
| Zhao et al. | Using associated polymer gels to control conformance for high temperature and high salinity reservoirs | |
| SA517381291B1 (en) | Methods for Treating Subterranean Formations by Diverting Treatment Fluids | |
| CN108643876B (en) | Multi-dimensional pipe fracturing method for low-yield well of low-permeability oil field | |
| CN113356826B (en) | Moderate sand adding and pressure increasing acid fracturing method for improving fracture-cavity reservoir transformation effect | |
| CN113374459B (en) | Method for greatly improving recovery ratio by inhibiting ineffective circulation with low viscosity | |
| CN113123772B (en) | Efficient acid distribution method considering time-space distribution characteristics of acid-etched crack flow conductivity | |
| CN110671089B (en) | Fracturing filling process parameter optimization design method | |
| RU2579093C1 (en) | Method for repeated hydraulic fracturing | |
| CN107143319A (en) | The cold method adopted of shallow oil reservoir reducing thick oil viscosity | |
| CN102277151A (en) | Delayed crosslinking resistance-diminishing water-base fracturing fluid | |
| RU2711202C2 (en) | Method of limiting water influx in gas wells with abnormally low formation pressure | |
| RU2648135C1 (en) | Method of oil field development |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| CB03 | Change of inventor or designer information |
Inventor after: Liu Pingli Inventor after: Luo Zhifeng Inventor after: Lanxi Hall Inventor after: Li Nianyin Inventor after: Gao Shang Inventor after: Zhang Lu Inventor after: Zhang Liping Inventor after: Liu Yigang Inventor after: Yang Zhai Inventor after: Liu Changlong Inventor after: Meng Xianghai Inventor after: Du Juan Inventor after: Zou Jian Inventor after: Zhao Liqiang Inventor after: Chen Xiang Inventor before: Liu Yigang Inventor before: Luo Zhifeng Inventor before: Lanxi Hall Inventor before: Li Nianyin Inventor before: Gao Shang Inventor before: Zhang Lu Inventor before: Zhang Liping Inventor before: Liu Pingli Inventor before: Yang Zhai Inventor before: Liu Changlong Inventor before: Meng Xianghai Inventor before: Du Juan Inventor before: Zou Jian Inventor before: Zhao Liqiang Inventor before: Chen Xiang |
|
| CB03 | Change of inventor or designer information | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |