US20030150613A1 - Acidizing and scale treatment of subterranean formation - Google Patents
Acidizing and scale treatment of subterranean formation Download PDFInfo
- Publication number
- US20030150613A1 US20030150613A1 US10/055,823 US5582302A US2003150613A1 US 20030150613 A1 US20030150613 A1 US 20030150613A1 US 5582302 A US5582302 A US 5582302A US 2003150613 A1 US2003150613 A1 US 2003150613A1
- Authority
- US
- United States
- Prior art keywords
- acid
- scale inhibitor
- reducing agent
- phosphonates
- iron ions
- 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.)
- Abandoned
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 13
- 238000011282 treatment Methods 0.000 title abstract description 6
- 239000002455 scale inhibitor Substances 0.000 claims abstract description 29
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims abstract description 20
- -1 iron ions Chemical class 0.000 claims abstract description 20
- 239000002253 acid Substances 0.000 claims abstract description 17
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 17
- 229910052742 iron Inorganic materials 0.000 claims abstract description 17
- 239000002244 precipitate Substances 0.000 claims abstract description 10
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 claims abstract description 5
- 238000000034 method Methods 0.000 claims description 19
- 239000000243 solution Substances 0.000 claims description 16
- CIWBSHSKHKDKBQ-JLAZNSOCSA-N Ascorbic acid Chemical group OC[C@H](O)[C@H]1OC(=O)C(O)=C1O CIWBSHSKHKDKBQ-JLAZNSOCSA-N 0.000 claims description 11
- ABLZXFCXXLZCGV-UHFFFAOYSA-N Phosphorous acid Chemical group OP(O)=O ABLZXFCXXLZCGV-UHFFFAOYSA-N 0.000 claims description 9
- 239000000654 additive Substances 0.000 claims description 9
- 230000000996 additive effect Effects 0.000 claims description 9
- 150000003871 sulfonates Chemical class 0.000 claims description 8
- CIWBSHSKHKDKBQ-DUZGATOHSA-N D-araboascorbic acid Natural products OC[C@@H](O)[C@H]1OC(=O)C(O)=C1O CIWBSHSKHKDKBQ-DUZGATOHSA-N 0.000 claims description 7
- 239000004318 erythorbic acid Substances 0.000 claims description 7
- 235000010350 erythorbic acid Nutrition 0.000 claims description 7
- 229940026239 isoascorbic acid Drugs 0.000 claims description 7
- MUBZPKHOEPUJKR-UHFFFAOYSA-N Oxalic acid Chemical compound OC(=O)C(O)=O MUBZPKHOEPUJKR-UHFFFAOYSA-N 0.000 claims description 6
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 6
- 150000003014 phosphoric acid esters Chemical class 0.000 claims description 5
- 150000001252 acrylic acid derivatives Chemical class 0.000 claims description 4
- 239000007864 aqueous solution Substances 0.000 claims description 4
- 229920001577 copolymer Polymers 0.000 claims description 4
- 239000000203 mixture Substances 0.000 claims description 4
- 229920000058 polyacrylate Polymers 0.000 claims description 4
- 229920001897 terpolymer Polymers 0.000 claims description 4
- CWERGRDVMFNCDR-UHFFFAOYSA-N thioglycolic acid Chemical compound OC(=O)CS CWERGRDVMFNCDR-UHFFFAOYSA-N 0.000 claims description 4
- 230000002401 inhibitory effect Effects 0.000 claims description 3
- 239000000463 material Substances 0.000 claims description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 3
- 229920002125 Sokalan® Polymers 0.000 claims description 2
- 235000010323 ascorbic acid Nutrition 0.000 claims description 2
- 239000011668 ascorbic acid Substances 0.000 claims description 2
- 229960005070 ascorbic acid Drugs 0.000 claims description 2
- 238000006243 chemical reaction Methods 0.000 claims description 2
- 235000006408 oxalic acid Nutrition 0.000 claims description 2
- 239000004584 polyacrylic acid Substances 0.000 claims description 2
- NBIIXXVUZAFLBC-UHFFFAOYSA-N Phosphoric acid Chemical compound OP(O)(O)=O NBIIXXVUZAFLBC-UHFFFAOYSA-N 0.000 claims 2
- 229910000147 aluminium phosphate Inorganic materials 0.000 claims 1
- 229960004106 citric acid Drugs 0.000 claims 1
- 235000015165 citric acid Nutrition 0.000 claims 1
- 150000003839 salts Chemical class 0.000 claims 1
- 239000012530 fluid Substances 0.000 description 7
- 238000005755 formation reaction Methods 0.000 description 7
- UEZVMMHDMIWARA-UHFFFAOYSA-M phosphonate Chemical compound [O-]P(=O)=O UEZVMMHDMIWARA-UHFFFAOYSA-M 0.000 description 5
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 3
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 3
- 150000007513 acids Chemical class 0.000 description 3
- 239000001110 calcium chloride Substances 0.000 description 3
- 229910001628 calcium chloride Inorganic materials 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- RPNUMPOLZDHAAY-UHFFFAOYSA-N Diethylenetriamine Chemical compound NCCNCCN RPNUMPOLZDHAAY-UHFFFAOYSA-N 0.000 description 2
- 239000003795 chemical substances by application Substances 0.000 description 2
- 238000000151 deposition Methods 0.000 description 2
- 230000008021 deposition Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- BDAGIHXWWSANSR-UHFFFAOYSA-N methanoic acid Natural products OC=O BDAGIHXWWSANSR-UHFFFAOYSA-N 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- OSWFIVFLDKOXQC-UHFFFAOYSA-N 4-(3-methoxyphenyl)aniline Chemical compound COC1=CC=CC(C=2C=CC(N)=CC=2)=C1 OSWFIVFLDKOXQC-UHFFFAOYSA-N 0.000 description 1
- RDQQEDAEKCYVCA-UHFFFAOYSA-N F.S(N)(O)(=O)=O Chemical compound F.S(N)(O)(=O)=O RDQQEDAEKCYVCA-UHFFFAOYSA-N 0.000 description 1
- 239000002738 chelating agent Substances 0.000 description 1
- 239000007795 chemical reaction product Substances 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- NHFDKKSSQWCEES-UHFFFAOYSA-N dihydrogen phosphate;tris(2-hydroxyethyl)azanium Chemical compound OP(O)(O)=O.OCCN(CCO)CCO NHFDKKSSQWCEES-UHFFFAOYSA-N 0.000 description 1
- 150000002148 esters Chemical class 0.000 description 1
- 235000019253 formic acid Nutrition 0.000 description 1
- 239000012535 impurity Substances 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000001556 precipitation Methods 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 239000003643 water by type Substances 0.000 description 1
Classifications
-
- 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
- C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
-
- 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
Definitions
- This invention relates to the treatment of subterranean formations using acid and scale inhibitors.
- the invention involves a one-step process for acidizing and scale treatment of a formation.
- the second step consists of carrying out the squeeze operation with scale inhibitor.
- Another possibility is to treat the well sequentially by inserting pads of liquid between the HCl/spent acid and the fluids containing the scale inhibitor. These procedures are more expensive and result in more down time than a combined operation.
- the method of the present invention involves the steps of
- Each of the three fluid components of the treating solution may be as follows:
- Acid Typical well treating acids include aqueous solution of 1 to 38% HCl, with 15% HCl being preferred.
- Other acids include sulfamic acid hydrofluoric acid, acetic acid, formic acid, etc. and mixtures thereof.
- Scale inhibitor The preferred oil field scale inhibitors include phosphate esters, phosphonates, sulfonates, and polyacrylates. Other scale inhibitors include copolymers and terpolymers of acrylates, sulfonates and phosphonates, phosphinico polycarboxylic acids (PPCA) and mixtures thereof. Particularly useful scale inhibitors include 2-hydroxyethyl imino bis methylene phosphonic acid, fatty amine phosphonates, triethanolamine phosphate ester, DETA phosphonate (pentaphosphonates) and TETA phosphonate (hexaphosphonates).
- the additive for preventing or inhibiting the formation of a precipitate of iron ions and the scale inhibitor may take a variety of forms such as chelating agents, or agents for maintaining the iron ions in the ferrous state.
- the preferred additive is a reducing agent for reducing Fe +++ to Fe ++ .
- Example reducing agents include ascorbic acid, citric acid and thioglycolic acid, oxalic acid, and erythorbic acid and mixtures thereof.
- the preferred reducing agent is erythorbic acid.
- the three water soluble or dispersible components may be used in one solution, or pumped in any sequence. It is preferred that they be used in one treating solution in the following concentrations (wt. %): Most Preferred Preferred Range Range Range HCl 1-38 10-15 15 Scale Inhibitor 0.5-50 0.5-10 1-5 Additive (e.g. reducing agent) 0.05-50 0.1-5 0.1-1.0
- the treating fluid may be premixed (“batched”) or mixed continuously (“on the fly”) during injection. All of the components may be blended together or they may be injected in any sequence of 1, 2 and 3.
- the precipitate preventative e.g. reducing agent
- the iron ions reacts with the iron ions so that upon contact with the scale inhibitor, no precipitate is formed.
- the amount of treating fluid squeezed into the formation will depend on several factors including the degree of scaling, the type of scale, length of perforations, etc. From 1 to 100 barrels per foot of perforations will be satisfactory for most treatments.
- the squeeze operation may be carried out with other work over procedures and may be in accordance with procedures well known in the art, including the use of corrosion inhibitors and other well treating chemicals.
- precipitate preventative e.g. reducing agent
- Tests were run by adding 0.6 wt. % erythorbic acid (reducing agent) to Samples B, C, and D, followed by the addition of 3.5 wt. % of a scale inhibitor. The samples were observed for a precipitate. Comparison tests were run on Samples B, C, D without the addition of the erythorbic acid. Table I presents the results.
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Inorganic Chemistry (AREA)
- Preventing Corrosion Or Incrustation Of Metals (AREA)
- Cleaning And De-Greasing Of Metallic Materials By Chemical Methods (AREA)
Abstract
A one step squeeze treatment of a subterranean formation involves the treatment with a treating solution comprising an acid, a scale inhibitor, and a reducing agent. The presence of the reducing agent prevents the iron ions in the system from reacting with and forming a precipitate with the scale inhibitor and maintains the iron ions in the ferrous state.
Description
- This invention relates to the treatment of subterranean formations using acid and scale inhibitors. In a preferred aspect, the invention involves a one-step process for acidizing and scale treatment of a formation.
- The deposition of scale from both produced and source waters is common in oil-producing operations. Depositions occur downhole and in flow lines, separators, and other surface facilities. Scale is a problem in acid/scale squeeze operations where iron is present as an impurity either in the water or the reaction product of the acid with scale or oil field equipment. The reaction of the impure iron with scale inhibitors may produce solids that damage the formation or block production equipment. Because of the precipitation resulting from the mixing of the incompatible fluids, present procedures generally require two separate operations for wells that need both well work overs (e.g. acidizing) and scale squeezes. With two separate operations, the well is first treated with concentrated HCl, and the resulting spent acid is cleared out of the well. The second step consists of carrying out the squeeze operation with scale inhibitor. Another possibility is to treat the well sequentially by inserting pads of liquid between the HCl/spent acid and the fluids containing the scale inhibitor. These procedures are more expensive and result in more down time than a combined operation.
- The method of the present invention involves the steps of
- (a) injecting into a subterranean formation a treating solution of
- (i) an acid that reacts with downhole materials and equipment to form CaCl 2, and iron ions,
- (ii) a scale inhibitor, and
- (iii) an additive capable of preventing the scale inhibitor from forming a precipitate with iron ions; and
- (b) after a suitable shut in time, producing fluid from the well.
- Each of the three fluid components of the treating solution may be as follows:
- (1) Acid: Typical well treating acids include aqueous solution of 1 to 38% HCl, with 15% HCl being preferred. Other acids include sulfamic acid hydrofluoric acid, acetic acid, formic acid, etc. and mixtures thereof.
- (2) Scale inhibitor: The preferred oil field scale inhibitors include phosphate esters, phosphonates, sulfonates, and polyacrylates. Other scale inhibitors include copolymers and terpolymers of acrylates, sulfonates and phosphonates, phosphinico polycarboxylic acids (PPCA) and mixtures thereof. Particularly useful scale inhibitors include 2-hydroxyethyl imino bis methylene phosphonic acid, fatty amine phosphonates, triethanolamine phosphate ester, DETA phosphonate (pentaphosphonates) and TETA phosphonate (hexaphosphonates).
- (3) The additive for preventing or inhibiting the formation of a precipitate of iron ions and the scale inhibitor may take a variety of forms such as chelating agents, or agents for maintaining the iron ions in the ferrous state. The preferred additive, however, is a reducing agent for reducing Fe +++ to Fe++. Example reducing agents include ascorbic acid, citric acid and thioglycolic acid, oxalic acid, and erythorbic acid and mixtures thereof. The preferred reducing agent is erythorbic acid.
- The three water soluble or dispersible components may be used in one solution, or pumped in any sequence. It is preferred that they be used in one treating solution in the following concentrations (wt. %):
Most Preferred Preferred Range Range Range HCl 1-38 10-15 15 Scale Inhibitor 0.5-50 0.5-10 1-5 Additive (e.g. reducing agent) 0.05-50 0.1-5 0.1-1.0 - Operation
- In the oil field squeeze operation, the treating fluid may be premixed (“batched”) or mixed continuously (“on the fly”) during injection. All of the components may be blended together or they may be injected in any sequence of 1, 2 and 3.
- (1) injection of a solution HCl
- (2) addition of reducing agent
- (2) injection of the scale inhibitor solution.
- In either process, the precipitate preventative (e.g. reducing agent) reacts with the iron ions so that upon contact with the scale inhibitor, no precipitate is formed.
- The amount of treating fluid squeezed into the formation will depend on several factors including the degree of scaling, the type of scale, length of perforations, etc. From 1 to 100 barrels per foot of perforations will be satisfactory for most treatments.
- The squeeze operation may be carried out with other work over procedures and may be in accordance with procedures well known in the art, including the use of corrosion inhibitors and other well treating chemicals.
- Once the well is returned to production chemicals squeezed into the formation will slowly be produced along with well fluids and will treat the well.
- Bottle tests carried out at 180° F. to determine the compatibility of HCl or solutions and scaling agents with and without the precipitate preventative (e.g. reducing agent).
- The following aqueous solutions were prepared:
Sample Ingredients A 15% HCl B 15% HCl + 3,000 ppm Fe+3 C spent 15% HCl + 22 wt. % CaCl2 D spent 15% HCl + 22 wt. % CaCl2 + 3000 ppm Fe+3 - Tests were run by adding 0.6 wt. % erythorbic acid (reducing agent) to Samples B, C, and D, followed by the addition of 3.5 wt. % of a scale inhibitor. The samples were observed for a precipitate. Comparison tests were run on Samples B, C, D without the addition of the erythorbic acid. Table I presents the results.
- The tests on Sample D demonstrate the effectiveness of the presence of the reducing agent with the first 5 scale inhibitors tested.
TABLE I Sample A B C D Scale Inhibitor No EA With EA Without EA With EA Without EA With EA Without EA 2-hydroxyethyl imino bis Not run OK OK Not run OK OK Cloudy/ppt methylene phosphonic acid Fatty Amine phosphonate Not run Cloudy/ppt (1) OK Not run OK OK Cloudy/ppt (2) triethanolamine phosphate Not run OK OK Not run OK (4) OK Cloudy/ppt ester DETA phosphonate Not run Cloudy/ppt (1) Cloudy/ppt Not run OK (3) OK (?) Coundy/ppt (pentaphosphonate) BMHT phosphonate Not run OK Cloudy/ppt Not run OK Cloudy/ppt (1) Cloudy/ppt EDA phosphonate OK Cloudy/ppt (1) Cloudy/ppt Not run Cloudy/ppt Cloudy/ppt Cloudy/ppt polyvinylsulfonate Not run Not run OK Not run OK Not run OK polyacrylic acid OK OK OK Cloudy/ppt (5) Cloudy/ppt Not run Not run
Claims (15)
1. In a method of treating a subterranean formation with a treating solution containing acid and iron ions, the improvement wherein the treating solution further contains
(a) a scale inhibitor, and
(b) an additive capable of preventing or inhibiting the iron ions from forming a precipitate with the scale inhibitor:
2. The method of claim 1 wherein the iron ions enter the treating solution by the acid reacting with downhole equipment or materials.
3. The method of claim 1 wherein the acid is HCl.
4. The method of claim 3 wherein the additive is a reducing agent for reducing the iron ions to the ferrous state.
5. The method of claim 4 wherein the reducing agent is erythorbic acid.
6. The method of claim 4 wherein the scale inhibitor is selected from the group consisting of phosphonates, phosphate esters, polyacrylates, sulfonates, copolymers and terpolymers of acrylates, sulfonates and phosphonates, phosphinico polycarboxylic acid.
7. A method of treating a subterranean formation comprising the steps of
(a) mixing an aqueous solution of
(i) HCl,
(ii) a scale inhibitor, and
(iii) an additive for preventing or inhibiting the scale inhibitor from forming a precipitate with any iron ions in the water,
(b) injecting the treating solution into the formation whereby the reaction of the HCl with downhole equipment or materials forms iron ions and whereby the presence of an effective amount of the additive (iii) inhibits the iron ions from reacting with and forming a precipitate with the scale inhibitor.
8. The method of claim 7 wherein the HCl is present in a concentration of 1 to 38%.
9. The method of claim 7 wherein the scale inhibitor is selected from the group consisting of phosphonates, phosphate esters, and polyacrylic acid.
10. The method of claim 7 wherein the scale inhibitor is selected from the group consisting of phosphonates, phosphate esters, polyacrylates, sulfonates, copolymers and terpolymers of acrylates, sulfonates and phosphonates, phosphinico polycarboxylic acid, phosphoric acid and salts thereof and is present in the treating solution at a concentration of between 0.5 and 50 wt. %.
11. The method of claim 7 wherein the additive is a reducing agent and is present in the treating solution at a concentration of between 0.05 and 30 wt. %.
12. The method of claim 11 wherein the reducing agent is selected from the group consisting of erythorbic acid, ascorbic acid, citric acid, thioglycolic acid, oxalic acid and mixtures thereof.
13. An aqueous solution for treating a subterranean formation which comprises:
(a) From 5 to 28 wt. % HCl,
(b) From 0.5 to 10 wt. % of a scale inhibitor, and
(c) From 0.05 to 5 wt. % of a reducing agent for maintaining any iron in the treating solution in the ferrous state.
14. The treating solution of claim 13 wherein the scale inhibitor consisting of phosphonates, phosphate esters, polyacrylates, sulfonates, copolymers and terpolymers of acrylates, sulfonates and phosphonates, phosphinico polycarboxylic acid.
15. The treating solution of claim 13 wherein the reducing agent is erythorbic acid.
Priority Applications (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US10/055,823 US20030150613A1 (en) | 2002-01-22 | 2002-01-22 | Acidizing and scale treatment of subterranean formation |
| AU2003217235A AU2003217235A1 (en) | 2002-01-22 | 2003-01-22 | Acidizing and scale treatment of subterranean formation |
| PCT/US2003/001891 WO2003062344A2 (en) | 2002-01-22 | 2003-01-22 | Acidizing and scale treatment of subterranean formation |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US10/055,823 US20030150613A1 (en) | 2002-01-22 | 2002-01-22 | Acidizing and scale treatment of subterranean formation |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| US20030150613A1 true US20030150613A1 (en) | 2003-08-14 |
Family
ID=27609227
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| US10/055,823 Abandoned US20030150613A1 (en) | 2002-01-22 | 2002-01-22 | Acidizing and scale treatment of subterranean formation |
Country Status (3)
| Country | Link |
|---|---|
| US (1) | US20030150613A1 (en) |
| AU (1) | AU2003217235A1 (en) |
| WO (1) | WO2003062344A2 (en) |
Cited By (13)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20050037930A1 (en) * | 2003-08-13 | 2005-02-17 | Horton David P. | Drilling fluids, drilling fluids additives and methods useful for limiting tar sands accretion on metal surfaces |
| US20060112972A1 (en) * | 2004-11-30 | 2006-06-01 | Ecolab Inc. | Methods and compositions for removing metal oxides |
| US20070158067A1 (en) * | 2005-08-10 | 2007-07-12 | Zhijun Xiao | Scale Inhibitors Compatible with Sandstone Acidizing |
| US20090104358A1 (en) * | 2007-10-17 | 2009-04-23 | Jacam Chemicals, Llc | Corrosion and scale inhibition compositions and methods of use thereof |
| US20090151944A1 (en) * | 2007-12-14 | 2009-06-18 | Fuller Michael J | Use of Polyimides in Treating Subterranean Formations |
| US20090247431A1 (en) * | 2008-04-01 | 2009-10-01 | D V Gupta | Biodegradable anionic acid corrosion inhibitor comprising sarcosines |
| US20130118759A1 (en) * | 2011-11-11 | 2013-05-16 | Baker Hughes Incorporated | Agents for enhanced degradation of controlled electrolytic material |
| WO2015026325A1 (en) * | 2013-08-20 | 2015-02-26 | Halliburton Energy Services, Inc. | Methods and systems for iron control using a phosphinated carboxylic acid polymer |
| WO2015200241A1 (en) * | 2014-06-24 | 2015-12-30 | Schlumberger Norge As | Methods of inhibiting salt precipitation and corrosion |
| US10081758B2 (en) | 2015-12-04 | 2018-09-25 | Ecolab Usa Inc. | Controlled release solid scale inhibitors |
| US10865339B2 (en) | 2016-05-16 | 2020-12-15 | Championx Usa Inc. | Slow-release scale inhibiting compositions |
| US11142680B2 (en) | 2016-12-23 | 2021-10-12 | Championx Usa Inc. | Controlled release solid scale inhibitors |
| CN115605559A (en) * | 2019-12-30 | 2023-01-13 | 巴西石油公司（Br） | Method for combined use of scale remover and scale inhibitor |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| DE102009002555A1 (en) | 2008-04-22 | 2009-10-29 | Basf Se | Use of complexing agents for the prevention of asphaltene and/or naphthenate-precipitation from crude oil, comprising oil-soluble, divalent complexing agent |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3633672A (en) * | 1970-05-11 | 1972-01-11 | Dow Chemical Co | Inhibition of deposition of scale |
| US3724544A (en) * | 1971-06-21 | 1973-04-03 | Texaco Inc | Secondary recovery method |
| US6192987B1 (en) * | 1999-04-06 | 2001-02-27 | Halliburton Energy Services, Inc. | Metal corrosion inhibitors, inhibited acid compositions and methods |
| US6436154B1 (en) * | 2000-09-28 | 2002-08-20 | Fmc Wyoming Corporation | Use of dodecylbenzene sulfonic acid or salt as a scale inhibitor |
-
2002
- 2002-01-22 US US10/055,823 patent/US20030150613A1/en not_active Abandoned
-
2003
- 2003-01-22 WO PCT/US2003/001891 patent/WO2003062344A2/en not_active Ceased
- 2003-01-22 AU AU2003217235A patent/AU2003217235A1/en not_active Abandoned
Cited By (29)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7081438B2 (en) * | 2003-08-13 | 2006-07-25 | Brine -Add Fluids Ltd. | Drilling fluids, drilling fluids additives and methods useful for limiting tar sands accretion on metal surfaces |
| US20050037930A1 (en) * | 2003-08-13 | 2005-02-17 | Horton David P. | Drilling fluids, drilling fluids additives and methods useful for limiting tar sands accretion on metal surfaces |
| US20060112972A1 (en) * | 2004-11-30 | 2006-06-01 | Ecolab Inc. | Methods and compositions for removing metal oxides |
| US7611588B2 (en) * | 2004-11-30 | 2009-11-03 | Ecolab Inc. | Methods and compositions for removing metal oxides |
| US7950462B2 (en) | 2005-08-10 | 2011-05-31 | Schlumberger Technology Corporation | Scale inhibitors compatible with sandstone acidizing |
| US20070158067A1 (en) * | 2005-08-10 | 2007-07-12 | Zhijun Xiao | Scale Inhibitors Compatible with Sandstone Acidizing |
| US7703530B2 (en) * | 2005-08-10 | 2010-04-27 | Schlumberger Technology Corporation | Scale inhibitors compatible with sandstone acidizing |
| US20100200238A1 (en) * | 2005-08-10 | 2010-08-12 | Zhijun Xiao | Scale Inhibitors Compatible with Sandstone Acidizing |
| US20090104358A1 (en) * | 2007-10-17 | 2009-04-23 | Jacam Chemicals, Llc | Corrosion and scale inhibition compositions and methods of use thereof |
| US20090151944A1 (en) * | 2007-12-14 | 2009-06-18 | Fuller Michael J | Use of Polyimides in Treating Subterranean Formations |
| US7841411B2 (en) | 2007-12-14 | 2010-11-30 | Schlumberger Technology Corporation | Use of polyimides in treating subterranean formations |
| US8357640B2 (en) * | 2008-04-01 | 2013-01-22 | Baker Hughes Incorporated | Method of inhibiting corrosion with an alkyl sarcosinate |
| US20110224111A1 (en) * | 2008-04-01 | 2011-09-15 | D V Satyanarayana Gupta | Biodegradable anionic acid corrosion inhibitor comprising sarcosines |
| US20090247431A1 (en) * | 2008-04-01 | 2009-10-01 | D V Gupta | Biodegradable anionic acid corrosion inhibitor comprising sarcosines |
| US7994102B2 (en) * | 2008-04-01 | 2011-08-09 | Baker Hughes Incorporated | Method of treating an alloy surface with an alkyl sarcosinate |
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Also Published As
| Publication number | Publication date |
|---|---|
| WO2003062344A3 (en) | 2004-04-08 |
| WO2003062344A2 (en) | 2003-07-31 |
| AU2003217235A1 (en) | 2003-09-02 |
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