WO2009123491A1 - Additif pour fluide de fracturation hydraulique et procédé pour son utilisation - Google Patents
Additif pour fluide de fracturation hydraulique et procédé pour son utilisation Download PDFInfo
- Publication number
- WO2009123491A1 WO2009123491A1 PCT/RU2008/000188 RU2008000188W WO2009123491A1 WO 2009123491 A1 WO2009123491 A1 WO 2009123491A1 RU 2008000188 W RU2008000188 W RU 2008000188W WO 2009123491 A1 WO2009123491 A1 WO 2009123491A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- particle
- proppant
- additive
- fracture
- size
- Prior art date
Links
- 239000000654 additive Substances 0.000 title claims abstract description 35
- 230000000996 additive effect Effects 0.000 title claims abstract description 34
- 238000000034 method Methods 0.000 title claims abstract description 19
- 239000012530 fluid Substances 0.000 title claims abstract description 17
- 239000002245 particle Substances 0.000 claims description 66
- 239000000463 material Substances 0.000 claims description 14
- 229920000642 polymer Polymers 0.000 claims description 7
- 230000008859 change Effects 0.000 claims description 4
- 239000002131 composite material Substances 0.000 claims description 3
- 230000008569 process Effects 0.000 claims description 3
- 210000001787 dendrite Anatomy 0.000 claims description 2
- 239000004033 plastic Substances 0.000 claims description 2
- 229920003023 plastic Polymers 0.000 claims description 2
- 239000000126 substance Substances 0.000 claims description 2
- 229920003169 water-soluble polymer Polymers 0.000 claims description 2
- 230000015572 biosynthetic process Effects 0.000 abstract description 14
- 238000005755 formation reaction Methods 0.000 abstract description 14
- 230000002265 prevention Effects 0.000 abstract description 2
- 239000000835 fiber Substances 0.000 description 13
- 238000004519 manufacturing process Methods 0.000 description 6
- 239000000203 mixture Substances 0.000 description 5
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 230000003993 interaction Effects 0.000 description 3
- 230000035699 permeability Effects 0.000 description 3
- 239000002002 slurry Substances 0.000 description 3
- 210000004027 cell Anatomy 0.000 description 2
- 230000007423 decrease Effects 0.000 description 2
- 239000007857 degradation product Substances 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- KXGFMDJXCMQABM-UHFFFAOYSA-N 2-methoxy-6-methylphenol Chemical compound [CH]OC1=CC=CC([CH])=C1O KXGFMDJXCMQABM-UHFFFAOYSA-N 0.000 description 1
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- 241000237858 Gastropoda Species 0.000 description 1
- RRHGJUQNOFWUDK-UHFFFAOYSA-N Isoprene Chemical compound CC(=C)C=C RRHGJUQNOFWUDK-UHFFFAOYSA-N 0.000 description 1
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 1
- VVQNEPGJFQJSBK-UHFFFAOYSA-N Methyl methacrylate Chemical compound COC(=O)C(C)=C VVQNEPGJFQJSBK-UHFFFAOYSA-N 0.000 description 1
- 229920005372 Plexiglas® Polymers 0.000 description 1
- 239000004698 Polyethylene Substances 0.000 description 1
- 239000004721 Polyphenylene oxide Substances 0.000 description 1
- 229920005830 Polyurethane Foam Polymers 0.000 description 1
- 239000004372 Polyvinyl alcohol Substances 0.000 description 1
- 239000000853 adhesive Substances 0.000 description 1
- 230000001070 adhesive effect Effects 0.000 description 1
- 230000004888 barrier function Effects 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 229920002678 cellulose Polymers 0.000 description 1
- 239000001913 cellulose Substances 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 229920006037 cross link polymer Polymers 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 229920001971 elastomer Polymers 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000002708 enhancing effect Effects 0.000 description 1
- 239000002657 fibrous material Substances 0.000 description 1
- 239000000945 filler Substances 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 150000002500 ions Chemical class 0.000 description 1
- 229910052749 magnesium Inorganic materials 0.000 description 1
- 239000011777 magnesium Substances 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 229920001568 phenolic resin Polymers 0.000 description 1
- 229920000747 poly(lactic acid) Polymers 0.000 description 1
- 229920000570 polyether Polymers 0.000 description 1
- -1 polyethylene Polymers 0.000 description 1
- 229920000573 polyethylene Polymers 0.000 description 1
- 229920001195 polyisoprene Polymers 0.000 description 1
- 239000004626 polylactic acid Substances 0.000 description 1
- 239000002861 polymer material Substances 0.000 description 1
- 239000011496 polyurethane foam Substances 0.000 description 1
- 229920002451 polyvinyl alcohol Polymers 0.000 description 1
- 239000002244 precipitate Substances 0.000 description 1
- 230000002028 premature Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 239000012781 shape memory material Substances 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 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
- E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
-
- 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
-
- 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
- C09K8/80—Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
Definitions
- This invention is used in hydraulic fracturing of subterranean formations and is more particularly a method to minimize the proppant settling rate.
- Hydraulic fracturing is a primary tool for enhancing well productivity by placing or extending highly conductive fractures from the wellbore into the reservoir.
- Conventional hydraulic fracturing treatment is generally considered to have several distinct stages.
- hydraulic fracturing fluid is injected through wellbore into a subterranean formation at high rates and pressures.
- the fracturing fluid injection rate exceeds the filtration rate into the formation producing increasing hydraulic pressure at the sandface.
- the pressure exceeds a threshold value, the formation strata or rock cracks and fractures. Hydraulic fracture initiates and starts to propagate into the formation as injection of fracturing fluid continues.
- proppant is admixed to fracturing fluid and transported throughout hydraulic fracture.
- Proppant deposited in created fracture over the designed length mechanically prevents fracture from closure after injection stops.
- the production rate of oil/gas essentially depends upon the number of the parameters, including formation permeability, hydraulic pressure in the formation, properties of the production fluid, shape of the fracture, etc.
- the most essential parameter and the one, which can be controlled and tweaked in hydraulic fracturing is the proppant pack permeability.
- Proppant pack permeability essentially depends upon the proppant distribution in the fracture, which in turn depends on a proppant placement. One of the most significant mechanisms, occurring during proppant placement is the proppant settling.
- Fibers to aid in transporting, suspending and placing proppant or gravel in viscous carrier fluids otherwise having insufficient viscosity to prevent particulate settling.
- Fibers are given that have properties optimized for proppant transport but degrade after the treatment into degradation products that do not precipitate in the presence of ions in the water such as calcium and magnesium.
- Crosslinked polymer carrier fluids are identified that are not damaged by contaminants present in the fibers or by degradation products released by premature degradation of the fibers.
- U.S. patent application No. 20050011648Al teaches about a method and apparatus for controlling the flowback of proppants that have been placed inside fractures of a subterranean formation.
- the apparatus is defined by a plurality of solid balls, which comprise compressed springs that are encapsulated in a mass of fibrous material and an aqueous soluble mixture of a filler material and an adhesive.
- the solid balls are mixed in a viscous slurry and injected into the fractures with the proppants. Over time the aqueous soluble mixture dissolves releasing the compressed springs to fill the openings of the fractures.
- the fibrous network and expanded springs which remain, act as a filter or screen to restrict the proppants flow-back to the surface during production of the well.
- U.S. patent No. 5908073 improved methods of propping a fracture in a subterranean zone whereby the subsequent flow-back of the proppant is prevented are provided.
- the methods basically include the steps of placing a mixture of fibrous bundles and the proppant in the fracture while maintaining the fracture open and then allowing the fracture to close on the mixture of fibrous bundles and proppant.
- the aim of the present invention is creation of an additive that effectively prevents proppant settling and proppant slug settling and assists proppant transport. Size at least in one of dimensions of the new additive should be comparable with the fracture width.
- proppant or proppant slugs are suspended in a fracturing fluid for several hours, so proppant settling is an important issue.
- the present technical solution describes a particle of additive introduced into the hydraulic fracture and the method of using the additive.
- the particle has a two- or three-dimensional structure wherein the size of the particle at least in one direction is comparable with the fracture width.
- the minimal additive's particle size L min is (0.5 ⁇ 5.O)-W fJ - where W & is the average hydraulic fracture width at the end of fracturing treatment and most preferably the minimal particle size L min is 1.2-W f r.
- the coefficient is empirical.
- the particle can change shape, hardness or adhesion to the fracture surface in time or as a result of chemical or physical processes. This provides for the better interaction of the particle surface with the walls of the hydraulic fracture being formed.
- the particle surface should be sticky. This can be achieved using any known method, for example, by applying a sticky composition onto the surface of the additive or manufacturing the additive from a polymer having good adhesion.
- the particle is made from an elastico-plastic material.
- the particle can be made from, but not limited by, polyethylene, polyether or cross-linked rubber.
- the particle is made from a polymer material. This can be a water-soluble polymer, e.g. polylactic acid, polyvinyl alcohol etc. or an oil-soluble polymer e.g.
- the particle can also be made from a composite material e.g. ceramic-polymer composite or polyurethane foam.
- the particle may have fractal or dendrite structure.
- Said particles suspended in the hydraulic fracturing fluid are introduced into the hydraulic fracture.
- the particles are added together with the proppant.
- the preferred concentration of the particles is 0.5-50 g/1.
- the present invention describes an additive particle that has a size at least in one of dimensions not less or large than the fracture width at the end of or during fracturing treatment.
- the additive particle may be formed of a material which is relatively soft compared to the material of the fracture walls.
- the additive particle may be formed from a material which is relatively elastic compared to a proppant or rock properties and can change its shape under stresses and recover the shape after the stress is released.
- the additive particle is formed from a material which is soluble in the formation fluids or non- soluble or partially soluble.
- the new additive particle means a structure with a size at least in one of dimensions comparable or larger than the fracture width during fracturing treatment.
- Fig.l shows schematic representation of fiber's orientation for regular fiber-loaded proppant treatment (Fig.l a) and for new additive particles orientation (Fig.l b) at the end of a fracturing treatment.
- the following notations are used: well 1, propped fracture 2.
- Proppant particles are not shown.
- a limited number of fibers are in contact with both fracture walls.
- almost all new additive particles are in contact with both fracture walls; this physically prevents proppant from settling via wall- proppant-additive particle mechanical interactions.
- Additive particle has a specific shape and size providing good contact with both fracture walls.
- the additive particle has a specific shape and size providing good contact with both fracture walls at any orientation.
- this type of additive particles forms a net through the fracture which, as a physical barrier, slows down the process of proppant settling.
- the direct contact with both fracture walls makes this additive particle different firom conventional fibers which usually are oriented in parallel direction to fracture walls and often have no contact with both walls at the same time.
- the new additive particle has a size at least in one of dimensions comparable with fracture width at end of fracturing treatment.
- the end of job fracture width is a fracture width after a fracturing treatment but before fracture closure. It means that during pumping stage additive particles can have smaller size than the fracture width and change their shape and/or size with time.
- Fig. 2 An example of the material is shown in Fig. 2
- the material has two-dimensional structure (size X ⁇ size Y»size Z) and its smallest dimension 6 is 15 mm which is comparable with EOJ fracture width.
- the minimal additive particle size in three- dimensional space should be comparable with the end of job fracture width.
- Example of such material is shown in Fig.3.
- the material has three-dimensional structure (size X ⁇ size Y ⁇ size Z) and its smallest dimension 4 is 10 mm which is comparable with End of Job fracture width. Dashed line shows the XY plane. Size 4 is in ZX plane.
- FIG.4 Another example of the new material is shown in Fig.4.
- the material has three-dimensional structure (sizeX—sizeY—sizeZ) and its smallest dimension 6 is 15 mm which is comparable with end of job fracture width. Dashed line shows the XY plane. Size 5 is in XY plane.
- the settling rate of 6 ppa proppant slurry in YF 125 gel with 10 g/L of J501 fibers (average length is 12 mm) was about 0.3 m/h.
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Physics & Mathematics (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Environmental & Geological Engineering (AREA)
- Compositions Of Macromolecular Compounds (AREA)
Abstract
La présente invention est destinée à être utilisée dans la fracturation hydraulique de formations souterraines et concerne plus particulièrement un procédé visant à minimiser la vitesse de décantation de l’agent de soutènement. On parvient à empêcher la décantation de l’agent de soutènement et de bouchons d’agent de soutènement et à faciliter le transport de l’agent de soutènement si la taille du nouvel additif dans au moins une dimension est comparable à la largeur des fractures. Au cours du traitement de fracturation, l’agent de soutènement est suspendu dans le fluide de fracturation pendant plusieurs heures, aussi la décantation de l’agent de soutènement constitue-t-elle une question importante.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/RU2008/000188 WO2009123491A1 (fr) | 2008-03-31 | 2008-03-31 | Additif pour fluide de fracturation hydraulique et procédé pour son utilisation |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
PCT/RU2008/000188 WO2009123491A1 (fr) | 2008-03-31 | 2008-03-31 | Additif pour fluide de fracturation hydraulique et procédé pour son utilisation |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2009123491A1 true WO2009123491A1 (fr) | 2009-10-08 |
Family
ID=41135764
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/RU2008/000188 WO2009123491A1 (fr) | 2008-03-31 | 2008-03-31 | Additif pour fluide de fracturation hydraulique et procédé pour son utilisation |
Country Status (1)
Country | Link |
---|---|
WO (1) | WO2009123491A1 (fr) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9896923B2 (en) | 2013-05-28 | 2018-02-20 | Schlumberger Technology Corporation | Synchronizing pulses in heterogeneous fracturing placement |
WO2018170312A1 (fr) * | 2017-03-15 | 2018-09-20 | Baker Hughes, A Ge Company, Llc | Agents anti-sédiment d'agent de soutènement tridimensionnels compressibles |
Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5330005A (en) * | 1993-04-05 | 1994-07-19 | Dowell Schlumberger Incorporated | Control of particulate flowback in subterranean wells |
RU2185501C1 (ru) * | 2001-10-08 | 2002-07-20 | Девятов Василий Васильевич | Способ разработки нефтяной залежи со стабилизацией фильтрации пропантом |
US6752208B1 (en) * | 2003-01-08 | 2004-06-22 | Halliburton Energy Services, Inc. | Methods of reducing proppant flowback |
US20060157243A1 (en) * | 2005-01-14 | 2006-07-20 | Halliburton Energy Services, Inc. | Methods for fracturing subterranean wells |
-
2008
- 2008-03-31 WO PCT/RU2008/000188 patent/WO2009123491A1/fr active Application Filing
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5330005A (en) * | 1993-04-05 | 1994-07-19 | Dowell Schlumberger Incorporated | Control of particulate flowback in subterranean wells |
RU2185501C1 (ru) * | 2001-10-08 | 2002-07-20 | Девятов Василий Васильевич | Способ разработки нефтяной залежи со стабилизацией фильтрации пропантом |
US6752208B1 (en) * | 2003-01-08 | 2004-06-22 | Halliburton Energy Services, Inc. | Methods of reducing proppant flowback |
US20060157243A1 (en) * | 2005-01-14 | 2006-07-20 | Halliburton Energy Services, Inc. | Methods for fracturing subterranean wells |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9896923B2 (en) | 2013-05-28 | 2018-02-20 | Schlumberger Technology Corporation | Synchronizing pulses in heterogeneous fracturing placement |
WO2018170312A1 (fr) * | 2017-03-15 | 2018-09-20 | Baker Hughes, A Ge Company, Llc | Agents anti-sédiment d'agent de soutènement tridimensionnels compressibles |
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