WO2006018778A1 - Acidification de matrice de formations a contrastes de permeabilite eleves - Google Patents
Acidification de matrice de formations a contrastes de permeabilite eleves Download PDFInfo
- Publication number
- WO2006018778A1 WO2006018778A1 PCT/IB2005/052621 IB2005052621W WO2006018778A1 WO 2006018778 A1 WO2006018778 A1 WO 2006018778A1 IB 2005052621 W IB2005052621 W IB 2005052621W WO 2006018778 A1 WO2006018778 A1 WO 2006018778A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- zone
- acid
- fluid
- vda
- tubing
- Prior art date
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 43
- 230000035699 permeability Effects 0.000 title claims description 24
- 238000005755 formation reaction Methods 0.000 title abstract description 41
- 239000011159 matrix material Substances 0.000 title description 4
- 239000012530 fluid Substances 0.000 claims abstract description 82
- 239000002253 acid Substances 0.000 claims abstract description 71
- 238000000034 method Methods 0.000 claims abstract description 43
- 230000004936 stimulating effect Effects 0.000 claims abstract description 3
- 230000000638 stimulation Effects 0.000 claims description 33
- 238000002347 injection Methods 0.000 claims description 24
- 239000007924 injection Substances 0.000 claims description 24
- 239000004094 surface-active agent Substances 0.000 claims description 12
- 239000000203 mixture Substances 0.000 claims description 4
- KWIUHFFTVRNATP-UHFFFAOYSA-N Betaine Natural products C[N+](C)(C)CC([O-])=O KWIUHFFTVRNATP-UHFFFAOYSA-N 0.000 claims description 3
- KXDHJXZQYSOELW-UHFFFAOYSA-N Carbamic acid Chemical compound NC(O)=O KXDHJXZQYSOELW-UHFFFAOYSA-N 0.000 claims description 3
- 229960003237 betaine Drugs 0.000 claims description 2
- KWIUHFFTVRNATP-UHFFFAOYSA-O N,N,N-trimethylglycinium Chemical compound C[N+](C)(C)CC(O)=O KWIUHFFTVRNATP-UHFFFAOYSA-O 0.000 claims 1
- 238000011282 treatment Methods 0.000 abstract description 40
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 22
- 239000010410 layer Substances 0.000 description 22
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 description 17
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 description 16
- 229910052757 nitrogen Inorganic materials 0.000 description 12
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 description 11
- WCUXLLCKKVVCTQ-UHFFFAOYSA-M Potassium chloride Chemical compound [Cl-].[K+] WCUXLLCKKVVCTQ-UHFFFAOYSA-M 0.000 description 10
- 239000003795 chemical substances by application Substances 0.000 description 9
- 229920000642 polymer Polymers 0.000 description 9
- 230000007797 corrosion Effects 0.000 description 8
- 238000005260 corrosion Methods 0.000 description 8
- 238000006073 displacement reaction Methods 0.000 description 8
- 239000003995 emulsifying agent Substances 0.000 description 8
- 239000003112 inhibitor Substances 0.000 description 8
- 229910052742 iron Inorganic materials 0.000 description 8
- 238000005086 pumping Methods 0.000 description 7
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 7
- POAOYUHQDCAZBD-UHFFFAOYSA-N 2-butoxyethanol Chemical compound CCCCOCCO POAOYUHQDCAZBD-UHFFFAOYSA-N 0.000 description 6
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 description 6
- 239000012267 brine Substances 0.000 description 6
- 239000002904 solvent Substances 0.000 description 6
- 230000004888 barrier function Effects 0.000 description 5
- 238000002955 isolation Methods 0.000 description 5
- 239000001103 potassium chloride Substances 0.000 description 5
- 235000011164 potassium chloride Nutrition 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 239000002516 radical scavenger Substances 0.000 description 5
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 5
- 239000007787 solid Substances 0.000 description 5
- 125000006850 spacer group Chemical group 0.000 description 5
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 description 4
- VTLYFUHAOXGGBS-UHFFFAOYSA-N Fe3+ Chemical compound [Fe+3] VTLYFUHAOXGGBS-UHFFFAOYSA-N 0.000 description 4
- 150000007513 acids Chemical class 0.000 description 4
- 229910001447 ferric ion Inorganic materials 0.000 description 4
- 238000012360 testing method Methods 0.000 description 4
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 description 3
- CWYNVVGOOAEACU-UHFFFAOYSA-N Fe2+ Chemical compound [Fe+2] CWYNVVGOOAEACU-UHFFFAOYSA-N 0.000 description 3
- 230000002378 acidificating effect Effects 0.000 description 3
- 239000003638 chemical reducing agent Substances 0.000 description 3
- 239000012141 concentrate Substances 0.000 description 3
- 239000002283 diesel fuel Substances 0.000 description 3
- 229910001448 ferrous ion Inorganic materials 0.000 description 3
- 239000006260 foam Substances 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 239000003921 oil Substances 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- KCXVZYZYPLLWCC-UHFFFAOYSA-N EDTA Chemical compound OC(=O)CN(CC(O)=O)CCN(CC(O)=O)CC(O)=O KCXVZYZYPLLWCC-UHFFFAOYSA-N 0.000 description 2
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 description 2
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 description 2
- 239000000654 additive Substances 0.000 description 2
- 235000019270 ammonium chloride Nutrition 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 230000003111 delayed effect Effects 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 229930195733 hydrocarbon Natural products 0.000 description 2
- 150000002430 hydrocarbons Chemical class 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 230000035515 penetration Effects 0.000 description 2
- 229920002401 polyacrylamide Polymers 0.000 description 2
- 239000002356 single layer Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000000126 substance Substances 0.000 description 2
- OVSKIKFHRZPJSS-UHFFFAOYSA-N 2,4-D Chemical compound OC(=O)COC1=CC=C(Cl)C=C1Cl OVSKIKFHRZPJSS-UHFFFAOYSA-N 0.000 description 1
- GEGGDDNVHQPTCS-QXMHVHEDSA-N 2-[3-[[(z)-docos-13-enoyl]amino]propyl-dimethylazaniumyl]acetate Chemical compound CCCCCCCC\C=C/CCCCCCCCCCCC(=O)NCCC[N+](C)(C)CC([O-])=O GEGGDDNVHQPTCS-QXMHVHEDSA-N 0.000 description 1
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 description 1
- 102100023245 Asparagine-tRNA ligase, cytoplasmic Human genes 0.000 description 1
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 description 1
- 101000624939 Homo sapiens Asparagine-tRNA ligase, cytoplasmic Proteins 0.000 description 1
- 238000010306 acid treatment Methods 0.000 description 1
- 239000004480 active ingredient Substances 0.000 description 1
- 150000001336 alkenes Chemical class 0.000 description 1
- 125000000129 anionic group Chemical group 0.000 description 1
- 239000000440 bentonite Substances 0.000 description 1
- 229910000278 bentonite Inorganic materials 0.000 description 1
- SVPXDRXYRYOSEX-UHFFFAOYSA-N bentoquatam Chemical compound O.O=[Si]=O.O=[Al]O[Al]=O SVPXDRXYRYOSEX-UHFFFAOYSA-N 0.000 description 1
- 239000001110 calcium chloride Substances 0.000 description 1
- 229910001628 calcium chloride Inorganic materials 0.000 description 1
- 125000005587 carbonate group Chemical group 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 125000002091 cationic group Chemical group 0.000 description 1
- 239000002738 chelating agent Substances 0.000 description 1
- 238000004140 cleaning Methods 0.000 description 1
- ZPUCINDJVBIVPJ-LJISPDSOSA-N cocaine Chemical compound O([C@H]1C[C@@H]2CC[C@@H](N2C)[C@H]1C(=O)OC)C(=O)C1=CC=CC=C1 ZPUCINDJVBIVPJ-LJISPDSOSA-N 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 238000005094 computer simulation Methods 0.000 description 1
- 229920001577 copolymer Polymers 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 239000000839 emulsion Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- UAUDZVJPLUQNMU-KTKRTIGZSA-N erucamide Chemical group CCCCCCCC\C=C/CCCCCCCCCCCC(N)=O UAUDZVJPLUQNMU-KTKRTIGZSA-N 0.000 description 1
- QUSNBJAOOMFDIB-UHFFFAOYSA-O ethylaminium Chemical compound CC[NH3+] QUSNBJAOOMFDIB-UHFFFAOYSA-O 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 239000003349 gelling agent Substances 0.000 description 1
- 150000002429 hydrazines Chemical class 0.000 description 1
- 150000002443 hydroxylamines Chemical class 0.000 description 1
- 229950004354 phosphorylcholine Drugs 0.000 description 1
- 238000005554 pickling Methods 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 238000012552 review Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000011780 sodium chloride Substances 0.000 description 1
- 239000003381 stabilizer Substances 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- 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
- E21B43/27—Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
-
- 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
- C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—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
-
- 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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/30—Viscoelastic surfactants [VES]
Definitions
- the invention relates to a combination of Tubing Conveyed Perforation (TCP) and acidizing with the use of Viscoelastic Diverting Acid (VDA) for effective matrix stimulation of multiple zones having large permeability contrasts.
- TCP Tubing Conveyed Perforation
- VDA Viscoelastic Diverting Acid
- diversion is required to ensure stimulation of the entire interval, especially for carbonate formations.
- acid is injected into such a reservoir, it preferentially enters the more permeable zone or zones or the first zone or zones encountered. At some point, the operator must then stop injection, place a mechanical or chemical diverter to control subsequent leakoff into the already-treated zone, and then resume acid injection.
- Viscoelastic surfactant (VES) based self-diverting acid systems were developed as single fluid systems that stimulate and divert simultaneously for carbonate formations. Such as system has low viscosity as formulated and pumped, but it reduces the chances of forming a dominating wormhole or thief zone when it is injected because it temporarily forms a viscous barrier, which is developed as the acid is spent in the formation, because the fluid undergoes an increase in viscosity as the acid is spent. The viscous barrier forces the following acid into other zones that have lower injectivity so that those zones can also be effectively stimulated.
- the viscous barrier breaks down upon contacting produced hydrocarbon, produced water, produced preflush fluids, or postflush fluids, leaving no solid residue to cause formation damage to the rock, because the VES system contains no solids or polymer. This is a very effective treatment for a single zone, especially if it is not thick, and it can also be used in thick zones or multiple zones.
- One embodiment of the invention is a method of stimulating a subterranean formation penetrated by a wellbore involving perforating a first zone with a perforation string conveyed on tubing, followed by a first injection step made up of injecting a fluid including a self-diverting acid through the tubing into the first zone. Then the tubing is moved to a second zone, which is then perforated, followed by a second injection step made up of injecting fluid including a stimulation fluid into the second zone.
- the first zone is less permeable than the second zone, and, usually, fluid is not flowed back into the well from the formation between the first injection step and the second injection step.
- the stimulation fluid in the second step also includes self-diverting acid.
- the second injection step is followed by the successive steps of moving the tubing to a third zone and perforating the third zone, then injecting a fluid including a stimulation fluid into the third zone. In that case, generally before treatment the second zone is less permeable than the third zone. Also, generally, in that case fluid is not flowed back into the well from the formation between the second injection step and the step of injecting a fluid including a stimulation fluid into the third zone. In other embodiments, such cycles of perforation and injection are repeated.
- the first injection step includes injecting alternating stages of a fluid including an acid and a fluid including a viscoelastic diverting acid.
- the second injection step includes injecting alternating stages of a fluid containing an acid and a fluid containing a viscoelastic diverting acid.
- both injection steps include injecting alternating stages of a fluid containing an acid and a fluid containing a viscoelastic diverting acid.
- the self-diverting acid includes a betaine and/or an amidoamine oxide.
- TCP is Tubing Conveyed Perforation, where the tubing may be coiled or conventional tubing.
- TCP assembly When the tubing is conventional, jointed, tubing the method generally uses a permanent completion in which the perforation equipment (or "TCP assembly") remains in the well; where the tubing is coiled tubing; the perforation string (or "CT Perforating assembly”) is retrieved.
- TCP assembly the perforation equipment
- CT Perforating assembly the perforation string
- the method will generally be used with coiled tubing and will be described in terms of coiled tubing, but it is to be understood that the method is applicable to both types of tubing.
- TCP enables sequential perforation of different intervals, it also allows pumping of VDA though the conveying tubing.
- VDA being a highly effective self-diverting acid
- VDA also provides good leakoff control after the acidizing treatment of each perforated interval, as the spent VDA is highly viscous, and remains viscous during treatment, even at elevated temperatures.
- the VDA system is easily pumped through coiled tubing because it has low viscosity as formulated and contains no solids that could make pumping through the tubing difficult or that could cause damage by solids in the newly created conductive channels.
- the surfactant gel breaks down on contact with, for example, produced oil, or condensate and mutual solvent preflush flowback, or when diluted with produced formation brine during flowback.
- a preflush or postflush (also called overflush) solution enhances the breakdown of the gelled surfactant and promotes quick cleanup.
- the method eliminates the need for a) mechanical zonal isolation, b) injection of many fluids, c) injection of solids, and d) multiple trips downhole.
- the highest permeability region is, by the nature of the conventional treatment, treated first.
- the lowest permeability region is stimulated first.
- the tubing conveyed perforation technique is combined with the use of a self-diverting acid fluid system (such as a VDA system) during acidizing to provide effective stimulation of layers (especially multiple layers) having large permeability contrasts, or layers extending over very large intervals.
- the disclosed process involves alternating stages of tubing conveyed perforation and acid treatment (which may be all VDA or may be VDA following or alternating with other acid), without wasteful pumping of additional fluid into the stimulated zones, after each acid injection, for control of leakoff during succeeding perforation and stimulation stages.
- the zone or zones are not isolated from one another, for example with packers, and separate diverters are not used.
- the method results in a much more homogeneous and uniform treatment of the entire thick or multi-zone system. After acidizing, there is usually near wellbore damage, resulting in a skin.
- the second zone treated is thin, or is the last zone to be treated, it may optionally be treated with acid only and not with VDA, but it is usually preferable to treat with VDA or alternating acid and VDA.
- the first stimulation fluid injected is acid, not VDA, although the first stimulation fluid may be acid if desired.
- the lowest permeability zone is treated first.
- the acid is normally hydrochloric acid but may be any acid or mixture of acids, organic or inorganic, delayed or not, used for carbonate formation stimulation.
- the concentration is any concentration used for carbonate stimulation.
- hydrochloric acid the concentration range is from about 3% to about 36%, preferably from about 7.5% to about 20%.
- the acid in the VDA stage(s) is usually the same as the acid in the non-VDA stage(s) but need not be.
- the "acid" in the non-VDA stage(s) may also be a "non-acidic" stimulation fluid (sometimes called a non-acidic reactive solution or NARS) for example a chelating agent, such as an aminocarboxylic acid, such as ethylenediaminetetraacetic acid (EDTA).
- Delay may be by any method used to delay acids, for example by forming an emulsion.
- VDA fluid systems have been described in U. S. Patent No. 6,667,280 and U. S. Patent Application Publication No. 2003/0119680, both hereby incorporated in their entirety. They contain viscoelastic surfactants (VES 's), such as those described in those references, and acids, for example hydrochloric acid. Additional surfactants that may be used to form VDA systems are described in U. S. Patent No. 6,258,859, hereby incorporated in its entirety. Suitable surfactants for formation of VDA systems are, for example, betaines and amidoamine oxides or mixtures of these surfactants.
- the stimulation fluid/diverter fluid is left in the formation during the successive stages of treatment.
- Treatment/diverter fluid especially for example the fluid from the first stage, may be left in the formation for a long time. There is no need for removal or flowback of any fluids during any but the last stage; they are non-damaging.
- Treatment of the zones may be performed one after the other without flowback of each individual zone. Flowback is performed only after the last zone is treated. There is no urgency to remove the diverter fluid or the treatment fluid as quickly as possible, as there might be if it contained polymer. Polymer can be more damaging the longer it remains in a formation.
- the stimulation fluid injected into each zone acts as the diverting agent for the subsequent treatments without the need for mechanical isolation.
- Another major advantage is that not all of the diverter fluid must be removed, even at the end of the treatment. Any VES remaining, and not cleaned up, will be non-damaging.
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- General Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Agricultural Chemicals And Associated Chemicals (AREA)
- Feeding, Discharge, Calcimining, Fusing, And Gas-Generation Devices (AREA)
Abstract
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
MX2007000771A MX2007000771A (es) | 2004-08-16 | 2005-08-05 | Formaciones con altos niveles de contrastes en la permeabilidad y con acidificacion de la matriz. |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US60191204P | 2004-08-16 | 2004-08-16 | |
US60/601,912 | 2004-08-16 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2006018778A1 true WO2006018778A1 (fr) | 2006-02-23 |
Family
ID=35116055
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/IB2005/052621 WO2006018778A1 (fr) | 2004-08-16 | 2005-08-05 | Acidification de matrice de formations a contrastes de permeabilite eleves |
Country Status (2)
Country | Link |
---|---|
MX (1) | MX2007000771A (fr) |
WO (1) | WO2006018778A1 (fr) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10787901B2 (en) | 2016-09-16 | 2020-09-29 | Halliburton Energy Services, Inc. | Dynamically optimizing a pumping schedule for stimulating a well |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20020092650A1 (en) * | 2000-02-15 | 2002-07-18 | Tolman Randy C. | Method and apparatus for stimulation of multiple formation intervals |
WO2004020788A1 (fr) * | 2002-08-30 | 2004-03-11 | Schlumberger Canada Limited | Fluides de traitement de reservoir |
-
2005
- 2005-08-05 MX MX2007000771A patent/MX2007000771A/es active IP Right Grant
- 2005-08-05 WO PCT/IB2005/052621 patent/WO2006018778A1/fr active Application Filing
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20020092650A1 (en) * | 2000-02-15 | 2002-07-18 | Tolman Randy C. | Method and apparatus for stimulation of multiple formation intervals |
WO2004020788A1 (fr) * | 2002-08-30 | 2004-03-11 | Schlumberger Canada Limited | Fluides de traitement de reservoir |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10787901B2 (en) | 2016-09-16 | 2020-09-29 | Halliburton Energy Services, Inc. | Dynamically optimizing a pumping schedule for stimulating a well |
Also Published As
Publication number | Publication date |
---|---|
MX2007000771A (es) | 2007-04-02 |
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