CN115785931A - Chelating blocking remover system for removing inorganic scale of gas well and blocking removing method - Google Patents
Chelating blocking remover system for removing inorganic scale of gas well and blocking removing method Download PDFInfo
- Publication number
- CN115785931A CN115785931A CN202211314270.0A CN202211314270A CN115785931A CN 115785931 A CN115785931 A CN 115785931A CN 202211314270 A CN202211314270 A CN 202211314270A CN 115785931 A CN115785931 A CN 115785931A
- Authority
- CN
- China
- Prior art keywords
- working solution
- chelating
- inorganic scale
- scale
- mass
- 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.)
- Pending
Links
- 230000000903 blocking effect Effects 0.000 title claims abstract description 20
- 238000000034 method Methods 0.000 title claims abstract description 20
- 239000012224 working solution Substances 0.000 claims abstract description 71
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims abstract description 60
- 239000002253 acid Substances 0.000 claims abstract description 33
- 239000002738 chelating agent Substances 0.000 claims abstract description 26
- 230000007797 corrosion Effects 0.000 claims abstract description 26
- 238000005260 corrosion Methods 0.000 claims abstract description 26
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 22
- 239000004927 clay Substances 0.000 claims abstract description 16
- 239000003381 stabilizer Substances 0.000 claims abstract description 16
- 239000003112 inhibitor Substances 0.000 claims abstract description 13
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 12
- 239000000654 additive Substances 0.000 claims abstract description 8
- 230000000996 additive effect Effects 0.000 claims abstract description 8
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims abstract description 8
- 229910052742 iron Inorganic materials 0.000 claims abstract description 8
- 239000013522 chelant Substances 0.000 claims abstract description 5
- 239000002270 dispersing agent Substances 0.000 claims abstract description 5
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 21
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 claims description 12
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 claims description 11
- 239000000126 substance Substances 0.000 claims description 11
- QAOWNCQODCNURD-UHFFFAOYSA-L Sulfate Chemical compound [O-]S([O-])(=O)=O QAOWNCQODCNURD-UHFFFAOYSA-L 0.000 claims description 10
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 9
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 claims description 9
- BPQQTUXANYXVAA-UHFFFAOYSA-N Orthosilicate Chemical compound [O-][Si]([O-])([O-])[O-] BPQQTUXANYXVAA-UHFFFAOYSA-N 0.000 claims description 9
- -1 iron ion Chemical class 0.000 claims description 8
- 239000002689 soil Substances 0.000 claims description 7
- AQLMHYSWFMLWBS-UHFFFAOYSA-N arsenite(1-) Chemical compound O[As](O)[O-] AQLMHYSWFMLWBS-UHFFFAOYSA-N 0.000 claims description 6
- RAXXELZNTBOGNW-UHFFFAOYSA-N imidazole Natural products C1=CNC=N1 RAXXELZNTBOGNW-UHFFFAOYSA-N 0.000 claims description 6
- 229920002401 polyacrylamide Polymers 0.000 claims description 6
- 239000001103 potassium chloride Substances 0.000 claims description 6
- 235000011164 potassium chloride Nutrition 0.000 claims description 6
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 5
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 4
- DBMJMQXJHONAFJ-UHFFFAOYSA-M Sodium laurylsulphate Chemical compound [Na+].CCCCCCCCCCCCOS([O-])(=O)=O DBMJMQXJHONAFJ-UHFFFAOYSA-M 0.000 claims description 4
- JVTAAEKCZFNVCJ-UHFFFAOYSA-N lactic acid Chemical compound CC(O)C(O)=O JVTAAEKCZFNVCJ-UHFFFAOYSA-N 0.000 claims description 4
- GCLGEJMYGQKIIW-UHFFFAOYSA-H sodium hexametaphosphate Chemical compound [Na]OP1(=O)OP(=O)(O[Na])OP(=O)(O[Na])OP(=O)(O[Na])OP(=O)(O[Na])OP(=O)(O[Na])O1 GCLGEJMYGQKIIW-UHFFFAOYSA-H 0.000 claims description 4
- 235000019982 sodium hexametaphosphate Nutrition 0.000 claims description 4
- 239000001577 tetrasodium phosphonato phosphate Substances 0.000 claims description 4
- 235000002639 sodium chloride Nutrition 0.000 claims description 3
- 239000011780 sodium chloride Substances 0.000 claims description 3
- 229920002907 Guar gum Polymers 0.000 claims description 2
- QPCDCPDFJACHGM-UHFFFAOYSA-N N,N-bis{2-[bis(carboxymethyl)amino]ethyl}glycine Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(=O)O)CCN(CC(O)=O)CC(O)=O QPCDCPDFJACHGM-UHFFFAOYSA-N 0.000 claims description 2
- IOVCWXUNBOPUCH-UHFFFAOYSA-M Nitrite anion Chemical compound [O-]N=O IOVCWXUNBOPUCH-UHFFFAOYSA-M 0.000 claims description 2
- 235000019270 ammonium chloride Nutrition 0.000 claims description 2
- 125000002485 formyl group Chemical class [H]C(*)=O 0.000 claims description 2
- 239000000665 guar gum Substances 0.000 claims description 2
- 229960002154 guar gum Drugs 0.000 claims description 2
- 235000010417 guar gum Nutrition 0.000 claims description 2
- 239000004310 lactic acid Substances 0.000 claims description 2
- 235000014655 lactic acid Nutrition 0.000 claims description 2
- 229920001495 poly(sodium acrylate) polymer Polymers 0.000 claims description 2
- NNMHYFLPFNGQFZ-UHFFFAOYSA-M sodium polyacrylate Chemical compound [Na+].[O-]C(=O)C=C NNMHYFLPFNGQFZ-UHFFFAOYSA-M 0.000 claims description 2
- UZVUJVFQFNHRSY-OUTKXMMCSA-J tetrasodium;(2s)-2-[bis(carboxylatomethyl)amino]pentanedioate Chemical compound [Na+].[Na+].[Na+].[Na+].[O-]C(=O)CC[C@@H](C([O-])=O)N(CC([O-])=O)CC([O-])=O UZVUJVFQFNHRSY-OUTKXMMCSA-J 0.000 claims description 2
- TZYULTYGSBAILI-UHFFFAOYSA-M trimethyl(prop-2-enyl)azanium;chloride Chemical compound [Cl-].C[N+](C)(C)CC=C TZYULTYGSBAILI-UHFFFAOYSA-M 0.000 claims description 2
- 238000010276 construction Methods 0.000 abstract description 5
- 230000008569 process Effects 0.000 abstract description 5
- 239000007789 gas Substances 0.000 description 27
- 239000003921 oil Substances 0.000 description 15
- IXCSERBJSXMMFS-UHFFFAOYSA-N hydrogen chloride Substances Cl.Cl IXCSERBJSXMMFS-UHFFFAOYSA-N 0.000 description 13
- 229960001484 edetic acid Drugs 0.000 description 10
- 230000000694 effects Effects 0.000 description 9
- 238000009826 distribution Methods 0.000 description 5
- 230000003628 erosive effect Effects 0.000 description 5
- 230000020477 pH reduction Effects 0.000 description 5
- 238000012360 testing method Methods 0.000 description 4
- 239000011575 calcium Substances 0.000 description 3
- UQSXHKLRYXJYBZ-UHFFFAOYSA-N iron oxide Inorganic materials [Fe]=O UQSXHKLRYXJYBZ-UHFFFAOYSA-N 0.000 description 3
- 229910044991 metal oxide Inorganic materials 0.000 description 3
- 150000004706 metal oxides Chemical class 0.000 description 3
- 229920000642 polymer Polymers 0.000 description 3
- 238000005303 weighing Methods 0.000 description 3
- KGIGUEBEKRSTEW-UHFFFAOYSA-N 2-vinylpyridine Chemical compound C=CC1=CC=CC=N1 KGIGUEBEKRSTEW-UHFFFAOYSA-N 0.000 description 2
- IRLPACMLTUPBCL-KQYNXXCUSA-N 5'-adenylyl sulfate Chemical compound C1=NC=2C(N)=NC=NC=2N1[C@@H]1O[C@H](COP(O)(=O)OS(O)(=O)=O)[C@@H](O)[C@H]1O IRLPACMLTUPBCL-KQYNXXCUSA-N 0.000 description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 2
- VTYYLEPIZMXCLO-UHFFFAOYSA-L Calcium carbonate Chemical compound [Ca+2].[O-]C([O-])=O VTYYLEPIZMXCLO-UHFFFAOYSA-L 0.000 description 2
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 239000004277 Ferrous carbonate Substances 0.000 description 2
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 2
- TZCXTZWJZNENPQ-UHFFFAOYSA-L barium sulfate Chemical compound [Ba+2].[O-]S([O-])(=O)=O TZCXTZWJZNENPQ-UHFFFAOYSA-L 0.000 description 2
- OSGAYBCDTDRGGQ-UHFFFAOYSA-L calcium sulfate Chemical compound [Ca+2].[O-]S([O-])(=O)=O OSGAYBCDTDRGGQ-UHFFFAOYSA-L 0.000 description 2
- 239000002041 carbon nanotube Substances 0.000 description 2
- 229910021393 carbon nanotube Inorganic materials 0.000 description 2
- 239000002131 composite material Substances 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- XPPKVPWEQAFLFU-UHFFFAOYSA-N diphosphoric acid Chemical compound OP(O)(=O)OP(O)(O)=O XPPKVPWEQAFLFU-UHFFFAOYSA-N 0.000 description 2
- 239000006185 dispersion Substances 0.000 description 2
- 238000001035 drying Methods 0.000 description 2
- 238000011156 evaluation Methods 0.000 description 2
- 238000002474 experimental method Methods 0.000 description 2
- RAQDACVRFCEPDA-UHFFFAOYSA-L ferrous carbonate Chemical compound [Fe+2].[O-]C([O-])=O RAQDACVRFCEPDA-UHFFFAOYSA-L 0.000 description 2
- 235000019268 ferrous carbonate Nutrition 0.000 description 2
- 229960004652 ferrous carbonate Drugs 0.000 description 2
- 238000001914 filtration Methods 0.000 description 2
- 230000002401 inhibitory effect Effects 0.000 description 2
- 230000005764 inhibitory process Effects 0.000 description 2
- 229910000015 iron(II) carbonate Inorganic materials 0.000 description 2
- 239000011777 magnesium Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 229910021645 metal ion Inorganic materials 0.000 description 2
- 239000000178 monomer Substances 0.000 description 2
- ZIUHHBKFKCYYJD-UHFFFAOYSA-N n,n'-methylenebisacrylamide Chemical compound C=CC(=O)NCNC(=O)C=C ZIUHHBKFKCYYJD-UHFFFAOYSA-N 0.000 description 2
- RGSFGYAAUTVSQA-UHFFFAOYSA-N pentamethylene Natural products C1CCCC1 RGSFGYAAUTVSQA-UHFFFAOYSA-N 0.000 description 2
- 238000002360 preparation method Methods 0.000 description 2
- 229940005657 pyrophosphoric acid Drugs 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- UBXAKNTVXQMEAG-UHFFFAOYSA-L strontium sulfate Chemical compound [Sr+2].[O-]S([O-])(=O)=O UBXAKNTVXQMEAG-UHFFFAOYSA-L 0.000 description 2
- 229920001897 terpolymer Polymers 0.000 description 2
- KXDHJXZQYSOELW-UHFFFAOYSA-N Carbamic acid Chemical compound NC(O)=O KXDHJXZQYSOELW-UHFFFAOYSA-N 0.000 description 1
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 1
- QXNVGIXVLWOKEQ-UHFFFAOYSA-N Disodium Chemical class [Na][Na] QXNVGIXVLWOKEQ-UHFFFAOYSA-N 0.000 description 1
- MBMLMWLHJBBADN-UHFFFAOYSA-N Ferrous sulfide Chemical compound [Fe]=S MBMLMWLHJBBADN-UHFFFAOYSA-N 0.000 description 1
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 1
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 1
- 229920002125 Sokalan® Polymers 0.000 description 1
- HCHKCACWOHOZIP-UHFFFAOYSA-N Zinc Chemical compound [Zn] HCHKCACWOHOZIP-UHFFFAOYSA-N 0.000 description 1
- 238000004220 aggregation Methods 0.000 description 1
- 230000002776 aggregation Effects 0.000 description 1
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 1
- 229910052788 barium Inorganic materials 0.000 description 1
- DSAJWYNOEDNPEQ-UHFFFAOYSA-N barium atom Chemical compound [Ba] DSAJWYNOEDNPEQ-UHFFFAOYSA-N 0.000 description 1
- 230000033558 biomineral tissue development Effects 0.000 description 1
- 239000012267 brine Substances 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 229910000019 calcium carbonate Inorganic materials 0.000 description 1
- 229910001424 calcium ion Inorganic materials 0.000 description 1
- 239000001506 calcium phosphate Substances 0.000 description 1
- 229910000389 calcium phosphate Inorganic materials 0.000 description 1
- 235000011010 calcium phosphates Nutrition 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 125000005587 carbonate group Chemical group 0.000 description 1
- 150000004649 carbonic acid derivatives Chemical class 0.000 description 1
- 150000001768 cations Chemical class 0.000 description 1
- 239000008139 complexing agent Substances 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 239000008398 formation water Substances 0.000 description 1
- 229910000037 hydrogen sulfide Inorganic materials 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 150000002506 iron compounds Chemical class 0.000 description 1
- KAEAMHPPLLJBKF-UHFFFAOYSA-N iron(3+) sulfide Chemical compound [S-2].[S-2].[S-2].[Fe+3].[Fe+3] KAEAMHPPLLJBKF-UHFFFAOYSA-N 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 229910052749 magnesium Inorganic materials 0.000 description 1
- ZLNQQNXFFQJAID-UHFFFAOYSA-L magnesium carbonate Chemical compound [Mg+2].[O-]C([O-])=O ZLNQQNXFFQJAID-UHFFFAOYSA-L 0.000 description 1
- 239000001095 magnesium carbonate Substances 0.000 description 1
- 229910000021 magnesium carbonate Inorganic materials 0.000 description 1
- 229910001425 magnesium ion Inorganic materials 0.000 description 1
- 229910052751 metal Inorganic materials 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 235000010755 mineral Nutrition 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000002343 natural gas well Substances 0.000 description 1
- NDLPOXTZKUMGOV-UHFFFAOYSA-N oxo(oxoferriooxy)iron hydrate Chemical compound O.O=[Fe]O[Fe]=O NDLPOXTZKUMGOV-UHFFFAOYSA-N 0.000 description 1
- 229910052760 oxygen Inorganic materials 0.000 description 1
- 239000001301 oxygen Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 238000005554 pickling Methods 0.000 description 1
- 239000004584 polyacrylic acid Substances 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000002455 scale inhibitor Substances 0.000 description 1
- 239000000377 silicon dioxide Substances 0.000 description 1
- 235000012239 silicon dioxide Nutrition 0.000 description 1
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 1
- DAJSVUQLFFJUSX-UHFFFAOYSA-M sodium;dodecane-1-sulfonate Chemical compound [Na+].CCCCCCCCCCCCS([O-])(=O)=O DAJSVUQLFFJUSX-UHFFFAOYSA-M 0.000 description 1
- 238000001179 sorption measurement Methods 0.000 description 1
- 229910052712 strontium Inorganic materials 0.000 description 1
- CIOAGBVUUVVLOB-UHFFFAOYSA-N strontium atom Chemical compound [Sr] CIOAGBVUUVVLOB-UHFFFAOYSA-N 0.000 description 1
- 150000003467 sulfuric acid derivatives Chemical class 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 230000002195 synergetic effect Effects 0.000 description 1
- QORWJWZARLRLPR-UHFFFAOYSA-H tricalcium bis(phosphate) Chemical compound [Ca+2].[Ca+2].[Ca+2].[O-]P([O-])([O-])=O.[O-]P([O-])([O-])=O QORWJWZARLRLPR-UHFFFAOYSA-H 0.000 description 1
- 230000004580 weight loss Effects 0.000 description 1
- 239000011701 zinc Substances 0.000 description 1
- 229910052725 zinc Inorganic materials 0.000 description 1
Images
Landscapes
- Gas Separation By Absorption (AREA)
Abstract
The invention discloses a chelate blockage removing agent system and a blockage removing method for removing inorganic scale of a gas well, wherein the chelate blockage removing agent system consists of three sets of working solutions, namely hydrochloric acid working solution, earth acid working solution and chelating agent working solution, wherein the components of the hydrochloric acid working solution comprise 15-20% of HC l, 2-4% of corrosion inhibitor, 0.5-2% of iron ion stabilizer, 1-2% of clay stabilizer, 0.1-0.5% of cleanup additive and the balance of water by mass percentage; the components of the earth acid working solution are 8-13% of HC l, 3% of HF, 2-4% of corrosion inhibitor, 0.5-2% of iron ion stabilizer, 1-2% of clay stabilizer, 0.1-0.5% of cleanup additive and the balance of water by mass fraction; the chelating agent working solution comprises 10-20% of chelating agent and 0.5-1% of dispersing agent by mass; the blockage removing method comprises the following steps: (1) injecting a hydrochloric acid working solution into a gas well shaft; (2) injecting an earth acid working solution into the shaft; (3) injecting a chelating agent working solution into the well bore; (4) And (4) returning the injected chelating blocking remover system to the ground to finish the whole construction process.
Description
Technical Field
The invention relates to a chelating blocking remover system for removing inorganic scale of a gas well and a blocking removing method, belonging to the technical field of oil and gas field development.
Background
The sulfates or carbonates of barium, strontium, magnesium and calcium are common inorganic scales in natural gas wells, stratum brine with high mineralization can generate rock salt aggregation due to changes of conditions such as temperature, pressure and the like, and meanwhile, various indissolvable iron compounds such as ferrous carbonate, ferric oxide, ferric sulfide and the like can be generated due to the existence of carbon dioxide, hydrogen sulfide and dissolved oxygen, and the generation of the inorganic scales has great harm to the development of oil and gas fields.
The existing descaling methods comprise chemical descaling, coiled tubing hydraulic jet descaling, coiled tubing mechanical descaling and the like. Wherein, the chemical descaling has the advantages of high blockage removing efficiency, wide range, low labor intensity and the like; the hydraulic jet descaling of the continuous oil pipe is greatly influenced by the size of a shaft, and the application range is limited; the mechanical descaling operation of the continuous oil pipe has high difficulty, high cost and high risk, the shaft cannot smoothly rotate, the descaling and blockage removing quality is poor, and the mechanical descaling operation can only be used for gas wells which are not suitable for acid pickling and cannot be descaled by acid; in contrast, the advantages of chemical descaling are more obvious.
The published 'a scale remover formula for an oil field downhole string' (with the application number of CN 202111380778.6) discloses a scale remover formula which comprises the following components in parts by weight: 2 parts of aminocarboxylate chelating agent, 2 parts of HAC (acetic acid), 1 part of high-efficiency penetrating agent, 3 parts of surfactant, 1 part of corrosion inhibitor, 15 parts of sodium dodecyl sulfonate, 2 parts of citric acid, 3 parts of disodium salt, 7 parts of polyacrylic acid, 4 parts of metal complexing agent and 3 parts of polypropyleneethanol. The patent application No. CN202111359512.3 discloses a scale-inhibiting and descaling agent, which comprises the following components: AMPS terpolymer, bis 1, 6-hexamethylene triamine pentamethylene phosphonic acid, pyrophosphoric acid, carbon nano tubes, 2-vinyl pyridine, N' -methylene bisacrylamide, sodium hexametaphosphate and water; the AMPS terpolymer, the bis-1, 6-hexamethylene triamine pentamethylene phosphonic acid and the sodium hexametaphosphate are adopted, so that the composite scale inhibitor has the effects of inhibiting and dispersing the scales such as carbonate, silicate, sulfate, calcium phosphate, zinc scale, iron oxide and the like, has high scale inhibition performance, is suitable for each component under the high-temperature condition to play a better synergistic effect, and can be used when a boiler runs; in the presence of N, N' -methylene bisacrylamide, pyrophosphoric acid, carbon nano tubes and vinyl pyridine are polymerized to prepare the composite adsorption compound with high scale inhibition and scale removal performance. "sandstone acidification scale remover and its preparation method" (application number CN 202011221006.3) disclose a scale remover and its preparation method, this scale remover is by monomer A and monomer B copolymerized polymer of 1; the weight average molecular weight of the polymer is 1000-1300 g/mol, and the molecular weight distribution coefficient is 1.1-1.2; the descaling agent for sandstone acidification is a polymer containing sulfonic groups, can be directly added into the prepared acidification working solution for use, can effectively remove calcium and magnesium ions in the acidification process, and does not influence the reaction or interaction between the acidification working solution and acid-erodible minerals or acid-soluble substances.
The invention aims to provide a chelating deblocking agent system aiming at the coexistence of inorganic scales such as sulfate, carbonate, metal oxide and the like.
Disclosure of Invention
Aiming at the problems of the background technology, the invention provides a chelating blocking remover system and a blocking remover method for removing inorganic scale of a gas well, which are used for efficiently removing the inorganic scale of the gas well shaft in the coexistence of sulfate, carbonate and metal oxide.
The invention provides a chelating deblocking agent system for removing inorganic scale of a gas well, which consists of three sets of working solutions, namely hydrochloric acid working solution, earth acid working solution and chelating agent working solution,
preferably, the hydrochloric acid working solution is used for dissolving carbonate components in inorganic scale; the earth acid working solution is used for dissolving away clay and silicate substances in inorganic scale; the chelating agent working solution is used for dissolving sulfate inorganic scale which is difficult to dissolve in acid in the inorganic scale.
Preferably, the components of the hydrochloric acid working solution are 15-20% of HCl, 2-4% of corrosion inhibitor, 0.5-2% of iron ion stabilizer, 1-2% of clay stabilizer, 0.1-0.5% of cleanup additive and the balance of water by mass fraction; the components of the earth acid working solution are 8-12% of HCl, 3% of HF, 2-4% of corrosion inhibitor, 0.5-2% of iron ion stabilizer, 1-2% of clay stabilizer, 0.1-0.5% of cleanup additive and the balance of water by mass fraction; the chelating agent working solution comprises 10-20% of chelating agent and 0.5-1% of dispersing agent by mass.
Preferably, the chelating agent is one or more of DTPA, EDTA, GLDA.
Preferably, the corrosion inhibitor is one of nitrite, arsenite, aldehyde corrosion inhibitor and imidazole corrosion inhibitor.
Preferably, the iron ion stabilizer is one of acetic acid, citric acid and lactic acid.
Preferably, the clay stabilizer is one or more of sodium chloride, potassium chloride, ammonium chloride and trimethyl allyl ammonium chloride.
Preferably, the cleanup additive is one of polyacrylamide and guar gum.
Preferably, the dispersant is one of sodium polyacrylate, sodium dodecyl sulfate and sodium hexametaphosphate.
The invention discloses a gas well inorganic scale blockage removing method, which uses the chelating blockage remover system for removing the gas well inorganic scale, and comprises the following steps:
s1, injecting a hydrochloric acid working solution into a gas well shaft;
s2, injecting the soil acid working solution into the shaft to fully erode the clay and silicate substances in the inorganic scale;
s3, injecting a chelating agent working solution into the shaft to fully erode sulfate inorganic scale which is difficult to dissolve in acid in the inorganic scale;
drawings
FIG. 1 is a flow chart of a plugging removal method for removing inorganic scale of a gas well.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings of the present invention, and it is obvious that the described embodiments are some, not all, embodiments of the present invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
The present invention will be described in detail below with reference to several examples.
Example 1
Firstly, preparing a chelating blocking remover system:
(1) Preparing hydrochloric acid working solution with the volume 1.2 times that of a shaft according to the volume of the shaft, wherein the formula comprises 20% of HCl, 3% of arsenite, 1% of citric acid, 1.5% of potassium chloride, 0.2% of polyacrylamide and the balance of water by mass percentage;
(2) Preparing a soil acid working solution with the volume 1.2 times that of a shaft according to the volume of the shaft, wherein the formula comprises 12% of HCl, 3% of HF, 3% of arsenite, 1% of citric acid, 1.5% of potassium chloride, 0.2% of polyacrylamide and the balance of water in percentage by mass;
(3) According to the volume of a shaft, chelating agent working solution with the volume 1.2 times that of the shaft is prepared, and the formula comprises EDTA (ethylene diamine tetraacetic acid) with the mass fraction of 20% and sodium dodecyl sulfate with the mass fraction of 1%.
It should be noted that the final effect of the formula of the earth acid working solution with HCl mass fraction of 12% to 13% is not much in the first embodiment, and therefore, redundant description is not necessary.
During field construction, the blockage removing method comprises the following steps:
(1) Injecting a hydrochloric acid working solution into a gas well shaft to ensure that the hydrochloric acid working solution is filled in the whole shaft space with inorganic scale distribution, and closing the well for 5 hours so as to fully erode carbonate components in the inorganic scale;
(2) Injecting an earth acid working solution into the shaft to ensure that the whole shaft space with inorganic scale is filled with the earth acid working solution, partially injecting the hydrochloric acid working solution in the step (1) into an oil gas reservoir, or returning the hydrochloric acid working solution to the ground through the shaft annulus or an oil pipe, closing the well for 5 hours, and fully dissolving clay and silicate substances in the inorganic scale by the earth acid working solution to be injected;
(3) Injecting a chelating agent working solution into the shaft to ensure that the chelating agent working solution is filled in the whole shaft space with inorganic scale distribution, wherein the soil acid working solution injected in the step (2) partially enters an oil gas reservoir and can also be returned to the ground through the shaft annulus or an oil pipe, closing the well for 5 hours, and fully dissolving and corroding the sulfate inorganic scale which is difficult to dissolve in acid in the inorganic scale by the chelating agent working solution to be injected;
(4) And (4) returning the injected chelate blocking remover system to the ground to finish the whole construction process.
Example 2
Firstly, preparing a chelating blocking remover system:
(1) Preparing a hydrochloric acid working solution with the volume 1.2 times that of a shaft according to the volume of the shaft, wherein the formula comprises 15% of HCl, 4% of arsenite, 2% of citric acid, 1.5% of potassium chloride, 0.2% of polyacrylamide and the balance of water by mass percentage;
(2) Preparing a soil acid working solution with the volume 1.2 times that of a shaft according to the volume of the shaft, wherein the formula comprises 8% of HCl, 3% of HF, 4% of arsenite, 2% of citric acid, 1.5% of potassium chloride, 0.2% of polyacrylamide and the balance of water by mass percentage;
(3) According to the volume of the shaft, chelating agent working solution with the volume 1.2 times that of the shaft is prepared, and the formula comprises EDTA with the mass fraction of 10% and sodium dodecyl sulfate with the mass fraction of 1%.
It should be noted that, in the above two embodiments, the content of HF in the earth acid working fluid may be in the range of 3% to 5% by mass, which can achieve the efficient blockage removal effect.
During the field construction, the blockage removing method comprises the following steps:
(1) Injecting a hydrochloric acid working solution into a well bore of the gas well, filling the whole well bore space with inorganic scale distribution with the hydrochloric acid working solution, and closing the well for 7 hours so as to fully erode carbonate components in the inorganic scale;
(2) Injecting an earth acid working solution into the shaft to ensure that the whole shaft space with inorganic scale is filled with the earth acid working solution, allowing part of the hydrochloric acid working solution injected in the step (1) to enter an oil gas reservoir, or returning the hydrochloric acid working solution to the ground through the shaft annulus or an oil pipe, closing the well for 7 hours, and fully dissolving and corroding clay and silicate substances in the inorganic scale by the earth acid working solution to be injected;
(3) Injecting a chelating agent working solution into the shaft to enable the chelating agent working solution to fill the whole shaft space with inorganic scale distribution, enabling part of the soil acid working solution injected in the step (2) to enter an oil and gas reservoir and also to be discharged back to the ground through the shaft annulus or an oil pipe, closing the well for 7 hours, and fully dissolving and eroding sulfate inorganic scale which is difficult to dissolve in acid in the inorganic scale by the chelating agent working solution to be injected;
(4) And (4) returning the injected chelating blocking remover system to the ground to finish the whole construction process.
The method for removing the inorganic scale of the gas well mainly comprises three steps of injecting hydrochloric acid working solution into a gas well shaft to inject the hydrochloric acid working solution into the gas well shaft; injecting a soil acid working solution into the shaft to fully erode clay and silicate substances in the inorganic scale; by injecting chelating agent working solution into the well bore, sulfate inorganic scale which is difficult to dissolve in acid in the inorganic scale is fully corroded.
And (3) performance testing:
the solubility was evaluated by taking the chelate blocking remover prepared in example 1 as an example.
The evaluation method comprises the following steps: (1) Taking a filter, drying the filter paper, cooling the filter paper in a dryer, and weighing the mass of the filter paper; weighing about 5g of dirty sample, and placing the dirty sample in a beaker; (3) Preparing 50mL of a chelating blocking remover, slowly adding the chelating blocking remover into a beaker containing a dirt sample, and then putting the beaker into a water bath at 90 ℃; (4) Preparing a filtering device, laying filter paper, fully reacting, filtering, drying, weighing, and recording the weight of the scale sample after corrosion; (5) Calculating the corrosion rate of the chelating blocking remover to the scale sample by using a weight loss method according to the following formula:
erosion rate (%) = (weight of scale sample before erosion (g) -weight of scale sample after erosion (g))/(weight of scale sample before erosion (g)) × 100%.
According to the above evaluation method, the corrosion rate of the chelating deblocking agent of example 1 on the scale sample was tested, and the corrosion rate of HCl (concentration 20%), HCl (concentration 12%) + HF (concentration 3%), EDTA (concentration 10%) on the scale sample under the same conditions was tested for comparison, three groups of experiments were tested, and the final corrosion rate was averaged over the three groups, and the test results are shown in table 1.
TABLE 1 Corrosion Rate under different conditions
Liquid name | HCl | HCl+HF | EDTA | Chelating blocking remover |
Rate of corrosion | 45.81% | 51.16% | 8.1% | 95.38% |
From the test results in table 1, the main component of the scale sample is carbonate inorganic scale, most of the carbonate rock inorganic scale can be dissolved by using HCl, HCl and HF, and the corrosion rates are 45.81% and 51.16%; when EDTA is used, because the dispersion effect is poor, the contact area of the EDTA and the scale sample is limited, the corrosion rate is only 8.1 percent, and the EDTA mainly chelates metal ions to ensure that the metal ions in the scale sample are dissolved in the solution; when the chelating deblocking agent provided by the invention is used for carrying out corrosion experiments, HCl and HF can dissolve most of carbonate, metal oxide, clay and silicate inorganic scales, the EDTA dispersion effect is good, the contact area of the chelating deblocking agent and a scale sample is large, the reaction is sufficient, the corrosion rate can reach 95.38%, and the effect is unexpectedly good.
The chelating blocking remover system-gas well inorganic scale corrosion effect test results are as follows:
TABLE 2 chelating deblocking agent System-gas well inorganic Scale Corrosion Effect Table
The field use effect is as follows:
example 1 was applied to a gas well in Sichuan. The gas well formation water contains a large amount of scale-forming cations Ca 2+ 、Mg 2+ And Ba 2+ Scaling phenomena are easy to occur, and scaling products block a shaft; the inorganic components of the plug are mainly ferrous sulfide, ferrous carbonate, calcium carbonate, magnesium carbonate, barium sulfate, calcium sulfate, strontium sulfate, silicon dioxide and the like; before inorganic scale of a shaft is removed, the oil pressure and the casing pressure of the well are both lower than 5MPa, and the gas production is almost 0 before the inorganic scale of the shaft is removed; the chelating deblocking agent system and the deblocking method of the embodiment 1 are adopted to remove inorganic scale in a shaft, the oil pressure and the casing pressure are increased to about 10MPa after deblocking, and the gas production is about 30 multiplied by 10 4 m 3 D, unblocking effectIs good.
The above description is only an embodiment of the present invention, and not intended to limit the scope of the present invention, and all modifications of equivalent structures and equivalent processes performed by the present specification and drawings, or directly or indirectly applied to other related technical fields, are included in the scope of the present invention.
Claims (10)
1. A chelate blocking remover system for removing inorganic scale of a gas well is characterized in that: the chelating deblocking agent system consists of three sets of working solutions, namely hydrochloric acid working solution, earth acid working solution and chelating agent working solution.
2. The chelating deblocking agent system for removing inorganic scale from gas wells as defined in claim 1, wherein: the hydrochloric acid working solution is used for dissolving carbonate components in inorganic scale; the earth acid working solution is used for dissolving away clay and silicate substances in inorganic scale; the chelating agent working solution is used for dissolving sulfate inorganic scale which is difficult to dissolve in acid in the inorganic scale.
3. The chelating deblocking agent system for removing inorganic scale of gas wells as claimed in claim 1, wherein the hydrochloric acid working solution comprises 15-20% by mass of HCl, 2-4% by mass of corrosion inhibitor, 0.5-2% by mass of iron ion stabilizer, 1-2% by mass of clay stabilizer, 0.1-0.5% by mass of cleanup additive, and the balance of water; the components of the earth acid working solution comprise 8-13% of HCl, 3-5% of HF, 2-4% of corrosion inhibitor, 0.5-2% of iron ion stabilizer, 1-2% of clay stabilizer, 0.1-0.5% of cleanup additive and the balance of water by mass percentage; the chelating agent working solution comprises 10-20% by mass of a chelating agent and 0.5-1% by mass of a dispersing agent.
4. The chelating deblocking agent system for removing inorganic scale from gas wells as recited in claim 2, wherein the chelating agent is one or more of DTPA, EDTA, GLDA.
5. The chelating deblocking agent system for removing inorganic scale from gas wells as defined in claim 2, wherein said corrosion inhibitor is one of nitrite, arsenite, aldehyde corrosion inhibitors, and imidazole corrosion inhibitors.
6. The chelating deblocking agent system for removing inorganic scale from gas wells as recited in claim 2, wherein the iron ion stabilizer is one of acetic acid, citric acid and lactic acid.
7. A chelating deblocking agent system for removing inorganic scale from gas wells as defined in claim 2, wherein said clay stabilizer is one or more of sodium chloride, potassium chloride, ammonium chloride, and trimethyl allyl ammonium chloride.
8. The chelating deblocking agent system for removing inorganic scale from gas wells according to any one of claims 2 to 6, wherein the cleanup additive is one of polyacrylamide and guar gum.
9. The chelating deblocking agent system for removing inorganic scale from gas wells as recited in claim 7, wherein the dispersant is one of sodium polyacrylate, sodium dodecyl sulfate, and sodium hexametaphosphate.
10. An inorganic scale blockage removing method for a gas well is characterized by comprising the following steps: the use of the chelating deblocking agent system of any one of claims 1 to 8 for the removal of gas well scale comprising:
s1, injecting a hydrochloric acid working solution into a gas well shaft;
s2, injecting the soil acid working solution into the shaft to fully erode the clay and silicate substances in the inorganic scale;
and S3, injecting a chelating agent working solution into the shaft to fully erode sulfate inorganic scale which is difficult to dissolve in acid in the inorganic scale.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CN202211314270.0A CN115785931A (en) | 2022-10-25 | 2022-10-25 | Chelating blocking remover system for removing inorganic scale of gas well and blocking removing method |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CN202211314270.0A CN115785931A (en) | 2022-10-25 | 2022-10-25 | Chelating blocking remover system for removing inorganic scale of gas well and blocking removing method |
Publications (1)
Publication Number | Publication Date |
---|---|
CN115785931A true CN115785931A (en) | 2023-03-14 |
Family
ID=85433757
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
CN202211314270.0A Pending CN115785931A (en) | 2022-10-25 | 2022-10-25 | Chelating blocking remover system for removing inorganic scale of gas well and blocking removing method |
Country Status (1)
Country | Link |
---|---|
CN (1) | CN115785931A (en) |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN108278098A (en) * | 2018-01-05 | 2018-07-13 | 中国石油天然气股份有限公司 | Gas field shaft blockage removing method |
CN114854384A (en) * | 2021-02-03 | 2022-08-05 | 中国石油天然气股份有限公司 | Blocking remover system and blocking removing method |
-
2022
- 2022-10-25 CN CN202211314270.0A patent/CN115785931A/en active Pending
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
CN108278098A (en) * | 2018-01-05 | 2018-07-13 | 中国石油天然气股份有限公司 | Gas field shaft blockage removing method |
CN114854384A (en) * | 2021-02-03 | 2022-08-05 | 中国石油天然气股份有限公司 | Blocking remover system and blocking removing method |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
CN101089118B (en) | Acidifying agent composition | |
US9512348B2 (en) | Removal of inorganic deposition from high temperature formations with non-corrosive acidic pH fluids | |
CN108865092B (en) | Slow-release chelating acid for water injection well plugging removal and injection increase, preparation method and plugging removal and injection increase method | |
US10975294B2 (en) | Injection stimulation agent for water injection well and the preparation method and application thereof | |
US4487265A (en) | Acidizing a subterranean reservoir | |
CN108690588A (en) | Environment-friendly type de-plugging of well system, preparation method and its method for removing blockage | |
BR112017009339B1 (en) | method | |
Chen et al. | Formulation of corrosion inhibitors | |
CN112111258B (en) | Water-lock injury blocking remover, use method thereof and water-lock injury acidizing fluid | |
CN112029489B (en) | Formula and preparation method of low-pressure gas field old well re-production blockage removing working solution | |
CN109913192A (en) | Desalination de-plugging agent | |
CN105368440A (en) | Novel environmental-friendly acidizing fluid suitable for acid-sensitive reservoir stratums, and preparation method thereof | |
CN109652043A (en) | One kind being suitable for the chemical plugging removal agent of tri compound drive injection well | |
CN111621276A (en) | Solid acid plugging agent and method for removing stratum plugging by using same | |
CN105754567B (en) | Water injection well scale remover and preparation method and application thereof | |
CN113214813A (en) | Chemical blocking remover for immobile pipe column of oil-water well and preparation method and application thereof | |
CN115785931A (en) | Chelating blocking remover system for removing inorganic scale of gas well and blocking removing method | |
CN108084979A (en) | A kind of barium and strontium sulfate descaling agent | |
CN111997576A (en) | Supermolecule microcosmic blockage removing method for stratum reconstruction of oil and gas field | |
SA98190109B1 (en) | Chemicals for an oil and gas field | |
CN114085659A (en) | Descaling blocking remover for high-temperature and high-pressure oil and gas wells and preparation method thereof | |
CN111826147B (en) | Soluble bridge plug cosolvent for horizontal well fracturing and soluble bridge plug dissolution assisting process | |
CN114854384A (en) | Blocking remover system and blocking removing method | |
CN107699220A (en) | Offshore oilfield well workover offensive well workover liquid system and its preparation method and application | |
CN114958324A (en) | Neutral anti-blocking blockage-removing and production-resuming working solution for old well of low-permeability gas field and preparation method thereof |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
PB01 | Publication | ||
PB01 | Publication | ||
SE01 | Entry into force of request for substantive examination | ||
SE01 | Entry into force of request for substantive examination | ||
RJ01 | Rejection of invention patent application after publication |
Application publication date: 20230314 |
|
RJ01 | Rejection of invention patent application after publication |