WO2015069230A1 - Composition fluide pour le nettoyage de puits de forage et de conduite et son procédé d'utilisation - Google Patents
Composition fluide pour le nettoyage de puits de forage et de conduite et son procédé d'utilisation Download PDFInfo
- Publication number
- WO2015069230A1 WO2015069230A1 PCT/US2013/068632 US2013068632W WO2015069230A1 WO 2015069230 A1 WO2015069230 A1 WO 2015069230A1 US 2013068632 W US2013068632 W US 2013068632W WO 2015069230 A1 WO2015069230 A1 WO 2015069230A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- effective amount
- composition
- wellbore
- parts per
- per million
- Prior art date
Links
- 239000000203 mixture Substances 0.000 title claims abstract description 22
- 239000012530 fluid Substances 0.000 title claims abstract description 20
- 238000000034 method Methods 0.000 title claims description 11
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 14
- 239000007788 liquid Substances 0.000 claims abstract description 13
- 239000000126 substance Substances 0.000 claims abstract description 12
- 239000007864 aqueous solution Substances 0.000 claims abstract description 9
- 238000004140 cleaning Methods 0.000 claims abstract description 7
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 15
- 229920002401 polyacrylamide Polymers 0.000 claims description 9
- 238000005553 drilling Methods 0.000 claims description 6
- 238000005086 pumping Methods 0.000 claims description 6
- POAOYUHQDCAZBD-UHFFFAOYSA-N 2-butoxyethanol Chemical compound CCCCOCCO POAOYUHQDCAZBD-UHFFFAOYSA-N 0.000 claims description 5
- 239000004205 dimethyl polysiloxane Substances 0.000 claims description 5
- 229920000435 poly(dimethylsiloxane) Polymers 0.000 claims description 5
- -1 polydimethylsiloxane copolymer Polymers 0.000 claims description 5
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 4
- 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 claims description 3
- 239000012267 brine Substances 0.000 claims description 3
- 229920000642 polymer Polymers 0.000 claims description 3
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 claims description 3
- 238000003780 insertion Methods 0.000 claims 1
- 230000037431 insertion Effects 0.000 claims 1
- 238000007789 sealing Methods 0.000 claims 1
- 239000004576 sand Substances 0.000 abstract description 7
- 238000005520 cutting process Methods 0.000 abstract description 4
- 230000015572 biosynthetic process Effects 0.000 description 16
- 238000005755 formation reaction Methods 0.000 description 16
- 239000007787 solid Substances 0.000 description 5
- 239000006187 pill Substances 0.000 description 4
- 239000000243 solution Substances 0.000 description 4
- 238000009825 accumulation Methods 0.000 description 3
- 230000035508 accumulation Effects 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 150000002430 hydrocarbons Chemical class 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 239000002245 particle Substances 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- GJCOSYZMQJWQCA-UHFFFAOYSA-N 9H-xanthene Chemical compound C1=CC=C2CC3=CC=CC=C3OC2=C1 GJCOSYZMQJWQCA-UHFFFAOYSA-N 0.000 description 1
- 244000007835 Cyamopsis tetragonoloba Species 0.000 description 1
- 150000003926 acrylamides Chemical class 0.000 description 1
- 150000001252 acrylic acid derivatives Chemical class 0.000 description 1
- 239000000654 additive Substances 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 239000003623 enhancer Substances 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 238000011010 flushing procedure Methods 0.000 description 1
- 239000008187 granular material Substances 0.000 description 1
- 229920006158 high molecular weight polymer Polymers 0.000 description 1
- 239000006194 liquid suspension Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 238000003801 milling Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000004062 sedimentation Methods 0.000 description 1
- 229920001285 xanthan gum Polymers 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
- E21B37/00—Methods or apparatus for cleaning boreholes or wells
- E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
-
- 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
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/06—Clay-free compositions
- C09K8/12—Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/28—Friction or drag reducing additives
Definitions
- This disclosure relates generally to the field of fluids used in subsurface wellbore, or pipeline cleaning. More specifically, the disclosure relates to the use of amphiphilic blends and friction reducers to enhance removal of sand and cuttings from wellbores, particularly after multi-zone fracturing operations.
- Wellbores drilled through subsurface formations include vertical and "horizontal" wells, i.e., those that are highly inclined from vertical up to and exceeding 90 degrees from vertical.
- the objective of drilling such wells is to penetrate a large area of a subsurface formation or formations that exist in layers having approximately the same orientation with respect to vertical, that is, the formations are highly inclined with respect to vertical.
- Some such formations include naturally or mechanically fractured zones, that is, zones where the formation has enhanced hydraulic permeability and conductivity due to tectonic stresses.
- Some fractured zones contain hydrocarbons in the form of oil and/or gas.
- a horizontal wellbore with fractured formation enhances the hydraulic interconnection of a large surface area of the formation to a single conduit, thereby making it economically feasible to produce the hydrocarbons.
- Hydraulic fracturing may further enable hydraulic connection of the formation located at a substantial lateral distance from the wellbore, thus enhancing the productivity of the wellbore further.
- Hydraulic fracturing includes pumping a liquid suspension of "proppant", which is a granular material whose grains are suitable to hold open a fracture created by the pressure of pumping the suspension into the formation after the pumping pressure is relieved.
- Hydraulic fracturing may be performed in some wellbores in a plurality of individual zones isolated by seal elements disposed in the wellbore after the individual zone has been hydraulically fractured. It may be necessary to remove the mechanical obstructions, excess cuttings and other debris from the wellbore in order to gain access to the entire horizontal wellbore for fracturing. It may also be necessary to remove excess fracture proppant, other debris and to remove the seal elements from the wellbore after hydraulic fracturing operations are finished in order to produce hydrocarbons commercially from the wellbore.
- the removal of debris, seals, and excess proppant from horizontal wellbores is typically facilitated through the use of a coil-tubing rig or work- over rig equipped with a bottom-hole tool assembly designed for milling debris into small particles and/or flushing the obstructions up the wellbore annulus to the surface.
- fluid system additives can be used to enhance well-bore cleaning operations.
- friction reducers such as high molecular weight polymers of acrylates, acrylamides, and derivatives thereof can be added to the fluid system to reduce pressure pumping requirements and build viscosity in the fluid.
- sand and debris removal from horizontal wellbores may be performed with intermittently pumped high viscosity "pills" of gel disposed in a high viscosity, concentrated water solution.
- the gel is a xanthan, guar, polyacrylamide (or derivative thereof), cellulostic polymer (or derivative thereof), or other polymeric material, which may be the same as used to suspend the proppant in the hydraulic fracturing operation.
- One aspect is a fluid composition for cleanout of wellbores drilled through subsurface formations that includes an effective amount of an amphiphilic chemical combined with an effective amount of a friction reducer in an aqueous solution of a base liquid. A remainder of the composition includes the base liquid.
- FIG. 1 is a cross section of a horizontal well after hydraulic fracturing.
- FIG. 2 shows cleaning out the wellbore of FIG. 1 using a coiled tubing system.
- FIG. 1 is a cross section of an example wellbore 10 drilled through subsurface formations by a drilling rig 12 or similar device well known in the art disposed at the Earth's surface 11.
- a drilling rig 12 or similar device well known in the art disposed at the Earth's surface 11.
- the wellbore 10 may be initially drilled vertically or near vertically, and when approaching a target formation 14, directional drilling equipment (not shown) may be used to change the trajectory of the wellbore at 10A so that it ultimately follows the trajectory at 10B of the target formation 14.
- the target formation 14 may be hydraulically fractured 20. Portions of the wellbore at 10B may be hydraulically isolated from each other using plugs 30 or similar mechanical seal devices to enable subsequent selective treatment, e.g., hydraulic fracturing of individual portions of the wellbore at 10B. [0014] After each such selective treatment, it may be required to clean out the excess fracturing proppant (e.g., sand) and to remove one or more of the plugs 30. Referring to FIG. 2, one example of such removal and cleaning operation may use a conduit contained on a coiled tubing unit 32 of types well known in the art to insert and withdraw a coiled tubing 32 from the wellbore 10B.
- fracturing proppant e.g., sand
- a distal end of the coiled tubing 34 may include an orienting device 36, sensors 38 of various types known in the art, an hydraulic motor 40 such as a positive displacement motor or a turbine motor operated by flow of fluid through the coiled tubing 34 and a bit or mill 42 at the distal end. Additional tools may be included in the bottom-hole assembly to facilitate the clean out including but not limited to agitators, reverse jet annular velocity enhancers, and mechanical tractors.
- fluid is pumped into the coiled tubing 34 such as by using a fluid pump 44, the motor 40 causes the bit or mill 42 to rotate, and cuttings and excess fracture proppant are lifted to the surface as the fluid exits the bit 42 and flows up an annular space between the coiled tubing 34 and the wall of the wellbore 10B.
- FIG. 2 is not meant to limit the types of conduit or conveyance apparatus that may be used in cleaning out a wellbore.
- Other types of conduit may include jointed tubing and drill pipe, and drilling rigs as in FIG. 1 or workover rigs may be used in such cleanout operations with equal effect.
- the fluid may include an effective amount of an amphiphilic chemical blended with an effective amount of a friction reducer in an aqueous solution.
- the amphiphilic chemical may be a single compound or a mixture of compounds.
- Two non-limiting examples of the amphiphilic chemical may include 2-butoxyethanol at a concentration of 2.4 to 24 parts per million in the aqueous solution combined with acetic acid at concentrations of 6 to 24 parts per million in the aqueous solution.
- Another example of the amphiphilic chemical may be polydimethylsiloxane copolymer at a concentration of about 100 to 300 parts per million in the aqueous solution.
- a friction reducer may include polyacrylamide, or an AMPS acrylamide polymer at a concentration of 70 to 150 parts per million in the aqueous solution.
- aqueous solution may be used to mean water or completion brine as the base liquid, or any other base liquid that is essentially non-reactive with the amphphilic chemical and the friction reducer.
- Effective amount with reference to the amphiphilic chemical and the friction reducer may mean an amount which optimizes the pressure pumping, flow rates, and removal of sand, debris and other particulate contaminants from the wellbore as a result of fluid flow out of the wellbore in the annular space between a conduit and the wall of the wellbore (explained below with reference to FIG. 2).
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- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geochemistry & Mineralogy (AREA)
- General Chemical & Material Sciences (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Lubricants (AREA)
Abstract
L'invention concerne une composition fluide pour le nettoyage de puits de forage et de systèmes de tuyaux comprenant une quantité efficace d'une substance chimique amphiphile combinée avec une quantité efficace d'un réducteur de frottement dans une solution aqueuse d'un liquide de base. Un reste de la composition comprend le liquide de base. La présente invention concerne généralement le domaine des fluides utilisés dans le nettoyage de puits de forage subsurface, ou de conduites. Plus spécifiquement, l'invention concerne l'utilisation de mélanges amphiphiles et de réducteurs de frottement pour améliorer l'élimination du sable et des déblais de puits de forage, en particulier après des opérations de fracturation multizones.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2013/068632 WO2015069230A1 (fr) | 2013-11-06 | 2013-11-06 | Composition fluide pour le nettoyage de puits de forage et de conduite et son procédé d'utilisation |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/US2013/068632 WO2015069230A1 (fr) | 2013-11-06 | 2013-11-06 | Composition fluide pour le nettoyage de puits de forage et de conduite et son procédé d'utilisation |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2015069230A1 true WO2015069230A1 (fr) | 2015-05-14 |
Family
ID=53041848
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2013/068632 WO2015069230A1 (fr) | 2013-11-06 | 2013-11-06 | Composition fluide pour le nettoyage de puits de forage et de conduite et son procédé d'utilisation |
Country Status (1)
Country | Link |
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WO (1) | WO2015069230A1 (fr) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2018038726A1 (fr) * | 2016-08-24 | 2018-03-01 | Halliburton Energy Services, Inc. | Fluide de nettoyage de tube d'intervention enroulé |
Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6631764B2 (en) * | 2000-02-17 | 2003-10-14 | Schlumberger Technology Corporation | Filter cake cleanup and gravel pack methods for oil based or water based drilling fluids |
US7781380B2 (en) * | 2005-01-24 | 2010-08-24 | Schlumberger Technology Corporation | Methods of treating subterranean formations with heteropolysaccharides based fluids |
US7897547B1 (en) * | 2009-12-21 | 2011-03-01 | Schlumberger Technology Corporation | Viscoelastic surfactant rheology modifier |
US7950459B2 (en) * | 2009-01-15 | 2011-05-31 | Schlumberger Technology Corporation | Using a biphasic solution as a recyclable coiled tubing cleanout fluid |
US8186438B2 (en) * | 2009-07-24 | 2012-05-29 | Schlumberger Technology Corporation | Wellbore debris cleanout with coiled tubing using degradable fibers |
US20120175108A1 (en) * | 2011-01-07 | 2012-07-12 | Weatherford/Lamb, Inc. | Test packer and method for use |
US20120214714A1 (en) * | 2011-02-18 | 2012-08-23 | Snf Holding Company | Process for achieving improved friction reduction in hydraulic fracturing and coiled tubing applications in high salinity conditions |
-
2013
- 2013-11-06 WO PCT/US2013/068632 patent/WO2015069230A1/fr active Application Filing
Patent Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6631764B2 (en) * | 2000-02-17 | 2003-10-14 | Schlumberger Technology Corporation | Filter cake cleanup and gravel pack methods for oil based or water based drilling fluids |
US7781380B2 (en) * | 2005-01-24 | 2010-08-24 | Schlumberger Technology Corporation | Methods of treating subterranean formations with heteropolysaccharides based fluids |
US7950459B2 (en) * | 2009-01-15 | 2011-05-31 | Schlumberger Technology Corporation | Using a biphasic solution as a recyclable coiled tubing cleanout fluid |
US8186438B2 (en) * | 2009-07-24 | 2012-05-29 | Schlumberger Technology Corporation | Wellbore debris cleanout with coiled tubing using degradable fibers |
US7897547B1 (en) * | 2009-12-21 | 2011-03-01 | Schlumberger Technology Corporation | Viscoelastic surfactant rheology modifier |
US20120175108A1 (en) * | 2011-01-07 | 2012-07-12 | Weatherford/Lamb, Inc. | Test packer and method for use |
US20120214714A1 (en) * | 2011-02-18 | 2012-08-23 | Snf Holding Company | Process for achieving improved friction reduction in hydraulic fracturing and coiled tubing applications in high salinity conditions |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2018038726A1 (fr) * | 2016-08-24 | 2018-03-01 | Halliburton Energy Services, Inc. | Fluide de nettoyage de tube d'intervention enroulé |
US11060011B2 (en) | 2016-08-24 | 2021-07-13 | Halliburton Energy Services, Inc. | Coil tubing cleanout fluid |
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