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WO2004067910A1 - Procedes de fracturation de zones souterraines - Google Patents

Procedes de fracturation de zones souterraines Download PDF

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Publication number
WO2004067910A1
WO2004067910A1 PCT/GB2003/005421 GB0305421W WO2004067910A1 WO 2004067910 A1 WO2004067910 A1 WO 2004067910A1 GB 0305421 W GB0305421 W GB 0305421W WO 2004067910 A1 WO2004067910 A1 WO 2004067910A1
Authority
WO
WIPO (PCT)
Prior art keywords
fracturing fluid
water
weight
amount
range
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.)
Ceased
Application number
PCT/GB2003/005421
Other languages
English (en)
Inventor
Philip C. Harris
Stephen W. Almond
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Halliburton Energy Services Inc
Original Assignee
Halliburton Energy Services Inc
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Priority to AU2003290257A priority Critical patent/AU2003290257A1/en
Publication of WO2004067910A1 publication Critical patent/WO2004067910A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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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
    • C09K8/60—Compositions for stimulating production by acting on the underground formation
    • C09K8/62—Compositions for forming crevices or fractures
    • C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
    • C09K8/706—Encapsulated breakers
    • 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
    • C09K8/685—Compositions based on water or polar solvents containing organic compounds containing cross-linking agents

Definitions

  • the present invention relates to methods of fracturing subterranean zones whereby maximum hydrocarbon productivity therefrom results.
  • Hydrocarbon producing wells are often stimulated by hydraulic fracturing treatments.
  • a viscous fracturing fluid which also functions as a carrier fluid is pumped into a producing zone to be fractured at a rate and pressure such that one or more fractures are formed in the zone.
  • Proppant particles e.g., graded sand, for propping the fractures are suspended in at least a portion of the fracturing fluid so that the proppant particles are deposited in the fractures when the fracturing fluid is broken. That is, a viscosity breaker is included in the fracturing fluid whereby the fracturing fluid reverts to a thin fluid which is returned to the surface.
  • the proppant particles deposited in the fractures when the fracturing fluid looses its viscosity function to prevent the fractures from closing so that conductive channels are formed through which produced hydrocarbons can readily flow.
  • the fracturing fluids utilized heretofore have damaged the proppant particle packs formed in the fractures whereby the production of hydrocarbons through the proppant particle packs is less than the maximum possible.
  • the damage has been the result of gelled fracturing fluid that forms a filter cake on the fracture faces subsequently flowing into the proppant particle packs. That is, after the fracturing fluid is recovered from the subterranean zone in which the fractures are formed and formation fluids are produced from the subterranean zone through the fractures and through the proppant packs therein, the gelled fracturing fluid filter cake on the fracture faces breaks up and flows into the proppant particle packs.
  • the fracturing fluids utilized heretofore have included high loadings of viscosity increasing gelling agents. When the fracturing fluids have been broken, i.e., reduced in viscosity, a significant amount of polymer residue attaches to the proppant particle packs thereby further reducing the produced hydrocarbon conductivity of the packs.
  • the present invention provides improved methods of fracturing subterranean zones whereby maximum hydrocarbon productivity results therefrom which meet the needs described above and overcome the deficiencies of the prior art.
  • the methods of the present invention utilize a fracturing fluid which is comprised of fresh water or salt water having a low salt content, a gelling agent and an inorganic salt for preventing clay swelling.
  • the gelling agent and the inorganic salt are included in the fracturing fluid in very low amounts so that the fracturing fluid produces very little damage to the conductivities of the proppant particle packs placed in the fractures.
  • the fracturing fluids utilized in accordance with the methods of this invention produce little or no gelled fracturing fluid, filter cake or residue in the permeable proppant particle packs thereby allowing maximum production of hydrocarbons from a fractured subterranean producing zone.
  • a fracturing fluid comprised of water, a gelling agent present in an amount in the range of from about 0.06% to about 0.3% by weight of the water and an inorganic salt for preventing clay swelling present in an amount in the range of from about 0.01% to about 1% by weight of the water.
  • the fracturing fluid is introduced into a subterranean zone at a rate and pressure sufficient to form one or more fractures in the zone. Thereafter, the fracturing fluid is recovered from the zone.
  • the fracturing fluid produces very little filter cake and/or residue in the formed fractures whereby the conductivities of the proppant particle packs in the fractures are not significantly impaired.
  • the present invention provides improved methods of fracturing subterranean zones whereby maximum hydrocarbon production from the zone is achieved.
  • the methods are basically comprised of the following steps.
  • a fracturing fluid comprised of water, a gelling agent present in an amount in the range of from about 0.06% to about 0.3% by weight of the water and an inorganic salt for preventing clay swelling present in an amount in the range of from about 0.01% to about 1% by weight of the water.
  • the fracturing fluid is introduced into a subterranean zone at a rate and pressure sufficient to form one or more fractures in the zone. Thereafter, the fracturing fluid is recovered from the zone.
  • the fracturing fluid generally also includes a cross-linking agent for the gelling agent which increases the viscosity of the fracturing fluid as well as suspended proppant particles and a delayed breaker for reducing the viscosity of the fracturing fluid.
  • a cross-linking agent for the gelling agent which increases the viscosity of the fracturing fluid as well as suspended proppant particles
  • a delayed breaker for reducing the viscosity of the fracturing fluid When the viscosity of the fracturing fluid is reduced, the suspended proppant particles are deposited in the formed fractures and the low viscosity fracturing fluid is recovered from the subterranean zone.
  • the water in the fracturing fluid is preferably fresh water, but it can also be salt water containing dissolved salts in no greater a concentration than about 3.5% by weight of the salt water.
  • gelling agents can be utilized in the fracturing fluid to provide viscosity thereto.
  • examples of gelling agents which can be utilized include, but are not limited to, galactomannans gums, modified or derivatized galactomannan gums, cellulose derivatives, xanthan biopolymer, succinoglycon biopolymer, polyacrylamides and polyacrylates.
  • galactomannan gums, modified or derivatized galactomannan gums and cellulose derivatives are generally preferred.
  • Suitable cellulose derivatives and galactomannan gums and derivatives include, but are not limited to, hydroxyethylcellulose, hydroxypropylguar, guar and anionically charged guar gelling agents such as carboxymethylguar, carboxymethylhydroxypropylguar, carboxymethylguar and carboxymethylhydroxyethylcellulose. Of these, the anionically charged guar gelling agents are preferred with carboxymethylhydroxypropylguar being the most preferred.
  • the gelling agent is included in the fracturing fluid in a minimum amount to prevent damage to the proppant packs in the formed fractures as described above.
  • the gelling agent is generally present in the fracturing fluid in an amount in the range of from about 0.06% to about 0.3% by weight of the water in the fracturing fluid. More preferably, the gelling agent is present in the fracturing fluid in an amount in the range of from about 0.12% to about 0.3% by weight of water therein, most preferably from about 0.18% to about 0.24%.
  • inorganic salts for preventing clay swelling can also be utilized.
  • examples of such inorganic salts include, but are not limited to, potassium chloride, sodium chloride, potassium nitrate and ammonium chloride. Of these, potassium chloride is preferred.
  • the inorganic salt utilized is included in the fracturing fluid in an amount in the range of from about 0.01% to about 1% by weight of the water in the fracturing fluid, more preferably in an amount in the range of from about 0.05% to about 0.5% by weight of the water and most preferably from about 0.1% to about 0.2%.
  • the fracturing fluid can also and generally does include a cross-linking agent for cross-linking the gelling agent and increasing the viscosity of the fracturing fluid.
  • a cross-linking agent for cross-linking the gelling agent and increasing the viscosity of the fracturing fluid.
  • cross-linking agents can be utilized, including, but not limited to, borate releasing compounds, a source of titanium ions, a source of zirconium ions, a source of antimony ions and a source of aluminum ions. Of these, a source of zirconium ions and a borate releasing compound such as boric acid, borax, ulexite and colemanite are preferred with a source of zirconium ions being the most preferred.
  • the cross-linking agent utilized is generally present in the fracturing fluid in an amount in the range of from about 0.02% to about 0.6% by weight of water therein and when a source of zirconium ions or a borate releasing compound is utilized from about 0.04% to about 0.3%.
  • the fracturing fluid generally also includes a delayed breaker for reducing the viscosity of the fracturing fluid whereby the fracturing fluid can be recovered from the subterranean zone.
  • delayed breakers which can be used include, but are not limited to, alkali metal and ammonium persulfates which are delayed by being encapsulated in a material which slowly releases the breaker, alkali metal chlorites, alkali metal hypochlorites and calcium hypochlorite. Of these, sodium chlorite is preferred.
  • the delayed breaker is generally included in the fracturing fluid in an amount in the range of from about 0.001% to about 0.25% by weight of water therein, more preferably from about 0.012% to about 0.06%.
  • the fracturing fluid includes proppant particles suspended therein which are deposited in the fractures formed when the viscosity of the fracturing fluid is reduced by the delayed breaker.
  • proppant particles can be used such as graded sand, bauxite particles, ceramic particles, glass particles, walnut hull particles, polymer particles and the like.
  • the proppant particles have a size in the range of from about 2 to about 400 mesh, U.S. Sieve Series.
  • the preferred proppant is graded sand having a particle size in the range of from about 10 to about 70 mesh, U.S. Sieve Series.
  • Preferred sand particle size distribution ranges are one or more of 10-20 mesh, 20-40 mesh, 40-60 mesh or 50-70 mesh, depending on the particular size and distribution of formation solids to be screened out by the consolidated proppant particles.
  • a preferred method of this invention for fracturing a subterranean zone whereby maximum hydrocarbon productivity therefrom results is comprised of the steps of: (a) providing a fracturing fluid comprised of water, a gelling agent present in an amount in the range of from about 0.06% to about 0.3% by weight of the water and an inorganic salt for preventing clay swelling present in an amount in the range of from about 0.01% to about 1% by weight of the water; (b) introducing the fracturing fluid into the subterranean zone at a rate and pressure sufficient to form one or more fractures in the zone; and (c) recovering the fracturing fluid from the zone.
  • Another preferred method of fracturing a subterranean zone whereby maximum hydrocarbon production therefrom results is comprised of the steps of: (a) providing a fracturing fluid comprised of water, a gelling agent selected from the group consisting of anionically charged guar gelling agents present in an amount in the range of from about 0.06% to about 0.3% by weight of the water, potassium chloride for preventing clay swelling present in an amount in the range of from about 0.1% to about 1% by weight of water, a cross-linking agent for cross-linking the gelling agent selected from the group consisting of a source of zirconium ions and a borate releasing compound present in an amount in the range of from about 0.04% to about 0.3% by weight of water and a sodium chlorite breaker present in an amount in the range of from about 0.001% to about 0.25% by weight of water; (b) introducing the fracturing fluid into the subterranean zone at a rate and pressure sufficient to form one or more fractures in the zone;
  • gelled fracturing fluids were prepared in the laboratory comprised of tap water, carboxymethylhydroxypropylguar gelling agent in an amount of 0.26% by weight of the water, various salts, i.e., potassium chloride, sodium chloride, ammonium chloride and potassium nitrate in amounts of 0.1% by weight of the water and a zirconium complex cross- linking agent in an amount of 0.04% by weight of the water.
  • various salts i.e., potassium chloride, sodium chloride, ammonium chloride and potassium nitrate in amounts of 0.1% by weight of the water
  • a zirconium complex cross- linking agent in an amount of 0.04% by weight of the water.
  • a 65 milliliter sample of each of the fracturing fluids was placed in a Fann Model 50 viscometer equipped with a 420 spring, a 316 stainless steel cup and a B2 bob.
  • the bath was preheated to 250°F and the fracturing fluid samples were each transferred into the viscometer cup at 75°F and placed on the viscometer.
  • the cup was rotated at 106 rpm (40 sec "1 ) and recovery was set at 5°F per minute.
  • the fracturing fluid sample viscosities and temperatures versus time were recorded. The results of the tests are given in the Table below.
  • fracturing fluids containing low concentrations of carboxymethylhydroxypropylguar and various inorganic salts for preventing clay swelling have sufficient viscosity to function successfully as fracturing fluids while producing very low filter cake and/or residue in the formed fractures.

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  • 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)
  • Compositions Of Macromolecular Compounds (AREA)

Abstract

L'invention concerne des procédés de fracturation de zones souterraines permettant d'obtenir une productivité maximum d'hydrocarbures. Ces procédés consistent de manière générale à utiliser un fluide de fracturation qui comprend: de l'eau; un agent de gélification présent à une quantité située dans la plage comprise entre environ 0,06 % et environ 0,3 % en poids d'eau; et un sel inorganique permettant de prévenir le gonflement des argiles, présent à une quantité située dans la plage comprise entre environ 0,01 % et environ 1 % en poids d'eau. Le fluide de fracturation est introduit dans la zone souterraine à une vitesse et à un pression suffisantes pour former des fractures, et est récupéré.
PCT/GB2003/005421 2003-01-28 2003-12-12 Procedes de fracturation de zones souterraines Ceased WO2004067910A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU2003290257A AU2003290257A1 (en) 2003-01-28 2003-12-12 Methods of fracturing subterranean zones to produce maximum productivity

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US10/352,406 US20040177965A1 (en) 2003-01-28 2003-01-28 Methods of fracturing subterranean zones to produce maximum productivity
US10/352,406 2003-01-28

Publications (1)

Publication Number Publication Date
WO2004067910A1 true WO2004067910A1 (fr) 2004-08-12

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PCT/GB2003/005421 Ceased WO2004067910A1 (fr) 2003-01-28 2003-12-12 Procedes de fracturation de zones souterraines

Country Status (3)

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US (1) US20040177965A1 (fr)
AU (1) AU2003290257A1 (fr)
WO (1) WO2004067910A1 (fr)

Families Citing this family (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
RU2324810C2 (ru) * 2006-05-31 2008-05-20 Шлюмберже Текнолоджи Б.В. Способ определения размеров трещины гидроразрыва пласта
US7712535B2 (en) * 2006-10-31 2010-05-11 Clearwater International, Llc Oxidative systems for breaking polymer viscosified fluids

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5393810A (en) * 1993-12-30 1995-02-28 Halliburton Company Method and composition for breaking crosslinked gels
US6138760A (en) * 1998-12-07 2000-10-31 Bj Services Company Pre-treatment methods for polymer-containing fluids
US6192985B1 (en) * 1998-12-19 2001-02-27 Schlumberger Technology Corporation Fluids and techniques for maximizing fracture fluid clean-up
EP1091086A1 (fr) * 1999-10-08 2001-04-11 Halliburton Energy Services, Inc. Compositions aqueuses gélifiées pour le traitement de puits de forage
US20020160920A1 (en) * 2001-02-22 2002-10-31 Jeffrey Dawson Breaker system for fracturing fluids used in fracturing oil bearing formations

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3766984A (en) * 1968-05-20 1973-10-23 Dow Chemical Co Method for temporarily sealing a permeable formation
US5964295A (en) * 1996-10-09 1999-10-12 Schlumberger Technology Corporation, Dowell Division Methods and compositions for testing subterranean formations

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5393810A (en) * 1993-12-30 1995-02-28 Halliburton Company Method and composition for breaking crosslinked gels
US6138760A (en) * 1998-12-07 2000-10-31 Bj Services Company Pre-treatment methods for polymer-containing fluids
US6192985B1 (en) * 1998-12-19 2001-02-27 Schlumberger Technology Corporation Fluids and techniques for maximizing fracture fluid clean-up
EP1091086A1 (fr) * 1999-10-08 2001-04-11 Halliburton Energy Services, Inc. Compositions aqueuses gélifiées pour le traitement de puits de forage
US20020160920A1 (en) * 2001-02-22 2002-10-31 Jeffrey Dawson Breaker system for fracturing fluids used in fracturing oil bearing formations

Also Published As

Publication number Publication date
AU2003290257A1 (en) 2004-08-23
US20040177965A1 (en) 2004-09-16

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