WO2015053928A1 - Fluide d'entretien de puits contenant un gaz d'hydrocarbure comprimé - Google Patents

Fluide d'entretien de puits contenant un gaz d'hydrocarbure comprimé Download PDF

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Publication number
WO2015053928A1
WO2015053928A1 PCT/US2014/056817 US2014056817W WO2015053928A1 WO 2015053928 A1 WO2015053928 A1 WO 2015053928A1 US 2014056817 W US2014056817 W US 2014056817W WO 2015053928 A1 WO2015053928 A1 WO 2015053928A1
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WO
WIPO (PCT)
Prior art keywords
well
fluid
servicing fluid
well servicing
chosen
Prior art date
Application number
PCT/US2014/056817
Other languages
English (en)
Inventor
D.V. Satyanarayana Gupta
Harpreet Singh Dinsa
Ronald Casey Plasier
Original Assignee
Baker Hughes Incorporated
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
Priority claimed from US14/047,592 external-priority patent/US20140034322A1/en
Application filed by Baker Hughes Incorporated filed Critical Baker Hughes Incorporated
Priority to MX2016004038A priority Critical patent/MX2016004038A/es
Priority to CN201480055477.8A priority patent/CN105722943A/zh
Publication of WO2015053928A1 publication Critical patent/WO2015053928A1/fr

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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
    • C09K8/82—Oil-based compositions
    • 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
    • C09K8/64—Oil-based compositions
    • 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

  • the present disclosure relates generally to a method for servicing a well with a fluid comprising a friction reducer and a nonaqueous carrier fluid.
  • Natural resources such as gas and oil can be recovered from subterranean formations using well-known techniques.
  • the processes for preparing a well bore for the recovery of such resources often employ various well bore servicing fluids.
  • One example of such fluids is hydraulic fracturing fluid, or "frac fluid”.
  • Frac fluids are employed in hydraulic fracturing, which is a common stimulation technique used to enhance production of fluids from subterranean formations in, for example, oil, gas, coal bed methane and geothermal wells.
  • hydraulic fracturing which is a common stimulation technique used to enhance production of fluids from subterranean formations in, for example, oil, gas, coal bed methane and geothermal wells.
  • a viscosified fracturing fluid is pumped at high pressures and high rates into a wellbore penetrating a subterranean formation to initiate and propagate a hydraulic fracture in the formation.
  • proppant e.g., graded sand, ceramic particles, bauxite, or resin
  • the proppant becomes deposited into the fractures, forming a permeable proppant pack.
  • the fracture closes onto the proppant pack, which maintains the fracture and provides a fluid pathway for hydrocarbons and/or other formation fluids to flow into the wellbore.
  • Well servicing fluids that contain water can also damage some well formations due to adverse water saturation effects, which can include what is known as sub- irreducible water saturation.
  • these formations When exposed to aqueous based fluids, these formations will trap water for long periods of time (e.g., permanently). The saturation of the formation with water can result in reduced permeability to hydrocarbons, which in turn can cause reduced productivity of the well.
  • An embodiment of the present disclosure is directed to a method of servicing a well.
  • the method comprises providing a well servicing fluid.
  • the well servicing fluid is formulated with the following components comprising, at least one friction reducer chosen from
  • polychloroprenes vinyl acetate polymers, polyalkylene oxides polyalphaolefms; and a nonaqueous carrier fluid.
  • the well servicing fluid is introduced into the well.
  • nonaqueous and/or hydrocarbon based well servicing fluids with reduced friction pressures can be formed; in some instances the friction reducing agents may provide relative ease of mixing with hydrocarbons; or the methods of the present application may provide reduced damage to well formations due to relatively low friction reducer treat rates and/or the ability to use nonaqueous well servicing fluids.
  • FIG. 1 shows a graph of friction loop pressure and flow rate versus RPM for 0.5 L/m 3 of FLO ® MXC and FLO MXA Friction Reducers compared with 0.5 L/ m 3 F-100 and 5 L/ m 3 F- 100, all mixed with FRACSOLTM at 30° C.
  • FIG. 2 show a graph of friction reduction verse Reynolds Number for 0.5 L/m 3 of FLO ® MXC and FLO MXA Friction Reducers compared with 5 L/ m 3 F-100, all mixed with FRACSOLTM at 30° C.
  • the present disclosure is directed to a method of servicing a well, such as, for example, natural gas, geothermal, coal bed methane or oil field wells.
  • the method comprises providing a well servicing fluid formulated with components comprising: at least one friction reducer chosen from polychloroprenes, vinyl acetate polymers, polyalkylene oxides and polyalphaolefins.
  • the well servicing fluid can be introduced into the well to perform various tasks, such as fracturing, frac packing or coiled tubing cleaning, as will be discussed in greater detail below.
  • the friction reducers are polymers capable of reducing friction pressure in a nonaqueous carrier fluid.
  • suitable friction reducers include polyalphaolefins.
  • the monomers used to form the polymer can be alpha olefins having from about 4 to about 16 carbon atoms.
  • the polymer is a polyalphaolefm homopolymer.
  • the polymer is a polyalphaolefm heteropolymer comprising at least two different alpha olefin repeating units.
  • Other suitable friction reducers include polychloroprenes, vinyl acetate polymers, and polyalkylene oxides. Mixtures of any of the polymer friction reducers described herein can also be employed.
  • the friction reducer can be polymerized using any suitable techniques. Examples of suitable techniques are well known in the art.
  • the resulting polymers can have molecular weights of, for example, above 10 million per analysis by gel permeation
  • polyalphaolefms examples include the FLO family of drag reducing agents available from Baker Pipeline Products, a division of Baker Performance Chemicals, Inc. These FLO family polyalphaolefms include FLO 1004, FLO 1005, FLO 1008, FLO 1010, FLO 1012, FLO 1020 and FLO 1022, among others.
  • the friction reducer can be in any suitable form that is capable of dissolution and/or mixing with the nonaqueous carrier fluid, such as a dispersion or liquid.
  • the friction reducer is a dispersion comprising polyalphaolefm particles.
  • the dispersion can further comprise at least one nonsolvent. Any suitable nonsolvent can be employed, including one or more compounds chosen from alcohols, including glycols and alkyl alcohols, such as isopropyl alcohol; glycol ethers, such as propylene glycol ether; ketones and esters.
  • a nonsolvent of the friction reducer is a material that does not dissolve the dispersed phase, e.g., the particles, in the friction reducer dispersion.
  • the nonsolvents can have, for example, from 2 to 6 carbon atoms.
  • the at least one nonsolvent comprises a glycol ether and an alkyl alcohol.
  • the dispersions employed in the present disclosure can contain other ingredients, such as solvents and anti-agglomeration agents.
  • suitable dispersions can be found in U.S. Patent Nos. 5,733,953 and 7,256,224, the disclosures of which are hereby incorporated by reference in their entirety.
  • suitable commercial dispersions include FLO MX ® , FLO MXC and FLO MXA drag reducing agent dispersions, all of which are available from Baker Petrolite Corp., which is a subsidiary of Baker Hughes of Houston Texas.
  • the concentration of friction reducer can vary depending on, among other things, the type of friction reducer, the carrier fluid in which it is used and the application for which the well servicing fluid is being employed.
  • Friction reducer concentrations can range, for example, from about 0.1 gptg (gallons per thousand gallons) to about 10 gptg, based on the total well servicing fluid, such as about 0.5 gptg to about 1 gptg. Ratios and concentrations outside of these ranges can also be employed.
  • nonaqueous carrier fluid that is usable for servicing a well can be employed.
  • nonaqueous fracturing fluids or coiled tubing cleaning fluids can be employed. Examples of such fluids are well known in the art.
  • nonaqueous carrier fluid as used herein is defined to mean a carrier fluid that contains 5% water by weight or less, based on the total weight of the carrier fluid. In embodiments, the nonaqueous carrier fluid can contain 1% by weight water or less, or substantially no water.
  • the nonaqueous carrier fluid comprises a hydrocarbon.
  • a hydrocarbon Any hydrocarbon that is suitable as a well servicing fluid, such as for fracturing, can be employed.
  • Suitable hydrocarbons include compressed hydrocarbon gas, such as liquefied hydrocarbon gas. That is, hydrocarbon gas may be compressed into a denser phase than occurs at atmospheric pressure or further compressed to the point that the gas is liquefied. Examples include compressed methane, propane, butane, or natural gas. Since compressed hydrocarbon gas might be available already at a well site, it may be beneficially used instead of other hydrocarbons that would be transported to the well site.
  • liquefied petroleum gas such as liquefied natural gas, or liquid carbon dioxide
  • a nonaqueous carrier fluid such as a nonaqueous fracturing fluid
  • suitable hydrocarbons include aliphatic C 6 to C 18 hydrocarbons, such as heptanes, octanes, nonanes, decanes, undecanes, dodecanes, tridecanes, tetradecanes, pentadecanes, and hexadecanes; and aromatic hydrocarbons, such as toluene and benzenes, including benzene, ethylbenzene, 1,2-dimethylbenzene, 1,3-dimethylbenzene, 1,4- dimethylbenzene, and trimethylbenzene; and mixtures of any of the above hydrocarbons.
  • the nonaqueous carrier can comprise aromatic hydrocarbons and aliphatic hydrocarbons.
  • N 2 and C0 2 Materials heretofore suggested for this purpose have been N 2 and C0 2 .
  • C0 2 can be successfully injected as a liquid.
  • N 2 due to the physical characteristics of N 2 , i.e., its extremely low critical temperature, it is customarily injected as a gas. Therefore, N 2 is limited in its usefulness and acceptability.
  • C0 2 has a critical temperature of 88° F and a critical pressure of 1072 pounds/inch 2 . These properties permit it to be injected as a liquid and thereafter to vaporize in the formation as the temperature of the injected fluid rises due to the heat of the formation.
  • a fluid that includes a liquefied gas, at least in part, and remains a liquid during the injection and treatment. Thereafter, the liquefied gas may revert to a gas, upon release of pressure at the wellhead and appreciable contact of the fluid with the warmer lower strata.
  • a compressed hydrocarbon fluid is employed of which the critical temperature and critical pressure can be adjusted to provide these conditions.
  • the compressed hydrocarbon fluid does not damage the formation and the flow back fluid might directly be put on a production pipeline without need for any treatment.
  • Examples of commercially available hydrocarbons include FRACSOLTM, which is available from Enerchem, located in Calgary, Alberta, Canada, and which contains a mixture of C 7 to Ci6 alkanes, toluene, benzene and xylene, as described in more detail in U.S. Patent No. 5,499,679, the disclosure of which is hereby incorporated by reference in its entirety; and XYSOL, a hydrocarbon suitable as a nonaqueous carrier fluid available from Enerchem, located in Calgary, Alberta, Canada.
  • the concentration of carrier fluid can vary depending on the type of carrier fluid and the application for which the well servicing fluid is being employed.
  • nonaqueous carrier concentrations can range, for example, from about 90 % by weight or more, such as about 98 % by weight to about 100% by weight, based on the total weight of the well servicing fluid.
  • a viscosifying agent is a viscosifying agent.
  • Any viscosifying agent suitable for adjusting the viscosity of nonaqueous fluids can potentially be used.
  • the viscosifying agent can be an oil gelling agent, such as a phosphate ester or an aluminum soap or aluminum fatty acid salt.
  • Employing phosphate esters, aluminums soaps or aluminum fatty acid salts as gelling agents is generally well known in the art.
  • the well servicing fluids do not include viscosifying agents, such as phosphate esters or aluminum soaps or aluminum fatty acid salts. Reducing or eliminating phosphate esters can have advantages, as phosphate esters are known to poison refinery catalysts and may have detrimental effects on the environment.
  • Proppants can be mixed with the well servicing fluids of the present application. Any suitable proppant can be employed. Proppants are generally well known for use in fracturing fluids. Examples of suitable proppant include graded sand, glass or ceramic beads or particles, sized calcium carbonate and other sized salts, bauxite grains, resin coated sand, walnut shell fragments, aluminum pellets, nylon pellets, and combinations of the above.
  • Proppants are well known to be used in concentrations ranging from about 0.05 to about 14 pounds per gallon (about 6 to about 1700 kg/m 3 ) of fracturing fluid composition, but higher or lower concentrations can be used as desired for the particular fracture design.
  • Known techniques for using proppant in liquefied petroleum gas, liquefied natural gas, or liquid carbon dioxide nonaqueous carrier fluids may be used with compressed hydrocarbon gas as the nonaqueous carrier fluid.
  • the well servicing fluid can further comprise either one or both of nitrogen gas (N 2 ) or carbon dioxide (C0 2 ), unless the nonaqueous carrier fluid is compressed hydrocarbon gas.
  • the nitrogen gas and carbon dioxide can be used to form a foam or emulsion with the well servicing fluid; the carbon dioxide is soluble in hydrocarbons and can alternatively be present as dissolved carbon dioxide.
  • Employing nitrogen gas and carbon dioxide in well servicing fluids is well known. It can provide various benefits, including reduced damage to the formation, improved cleanup, favorable energy transfer in the wellbore and good proppant carrying capability.
  • the well servicing fluid can comprise at least one additional compound chosen from breakers, non-emulsifiers, clay stabilization additives, scale dissolvers, biopolymer degradation additives, fluid loss control additives, high temperature stabilizers, and other common and/or optional components.
  • breakers are the only other ingredient used in compressed hydrocarbon gas as the nonaqueous carrier fluid.
  • the well servicing fluid can comprise relatively low concentrations of hydrocarbons that are not compressed gas, such as about 5% by weight or less, including, for example, about 2% by weight or less. In an embodiment, the well servicing fluid comprises substantially no hydrocarbons other than those that are compressed gas.
  • ingredients of the well servicing fluid can be combined in any suitable order using any suitable technique.
  • the friction reducer can be mixed with the friction reducer
  • nonaqueous carrier fluid such as compressed hydrocarbon gas
  • One of ordinary skill in the art would be able to formulate the well servicing fluids without undue experimentation given the guidance provided by the present disclosure.
  • the well servicing fluids of the present application can be employed as fracturing or frac pack fluids. Any suitable fracturing or frac packing technique can be employed. Various techniques for fracturing and frac packing wells are generally well known in the art.
  • the well servicing fluid which comprises a nonaqueous carrier fluid and a friction reducer of the present disclosure, is pumped into the well at a rate and a pressure sufficient to form fractures that extend into the subterranean formation, thereby providing additional pathways through which fluids being produced can flow into the well bores.
  • the well servicing fluid can include a proppant, including, for example, any of the proppants discussed herein. The proppant becomes deposited into the fractures and thus holds the fractures open after the pressure exerted on the fracturing fluid has been released.
  • any of the methods described herein can comprise removing the well servicing fluid from the well after the fluid contacts the formation. This removing step can be aided by gas pressure caused by carbon dioxide or nitrogen gas. Contacting the formation with the well service fluid and then removing the fluid can remove water from the formation. For effective removal of water from the formation, it is preferred that the well servicing fluid have reduced levels of water, such as any of the relatively low water concentrations discussed herein above. The removed well servicing fluid can be recovered, recycled or disposed of according to industry standard practices.
  • Removing the well servicing fluid can be performed at any time after the fluid contacts the formation.
  • the contacting step can be performed for a sufficient time for removing water, followed by the removing step.
  • the well can be "shut in", where the contacting step is performed for a prolonged period of time.
  • the length of time can be as short as immediate flow back or for up to several days (e.g. 2 or 3 days) shut in.
  • the above compositions were tested using a friction loop test apparatus.
  • the test apparatus included a 10 foot long, 1 ⁇ 4 inch outer diameter and 0.173 inch inner tubing equipped with a pressure gauge to measure friction pressure.
  • a triplex pump attached to an intake was used to pump the fluid from a 4L container via an intake and into the 1 ⁇ 4 inch tubing.
  • the 1 ⁇ 4 inch tubing was positioned so that the fluid flowed from the tubing into an inverted carboy having a 1 inch inner diameter coiled tubing to reduce velocity of the fluid.
  • the discharge from the carboy was returned to the 4L container to complete the loop.
  • a site glass was positioned to allow viewing of the fluid flow through the test apparatus.
  • FIG. 1 shows the friction loop pressure and flow rate versus RPM for compositions A-E above.
  • each of the FLO MXA and FLO MXC compositions provided significantly reduced friction loop pressures than the FRACSOL alone.
  • the FLO MXA and FLO MXC compositions at 1/10 the concentration (0.5 L/m 3 ), provided comparable or slightly better results than the F-100 at about ten times the concentration (5 L/m 3 ); and significantly reduced friction loop pressures than the F- 100 at 0.5 L/m 3 .
  • FIG. 1 shows the friction loop pressure and flow rate versus RPM for compositions A-E above.
  • each of the FLO MXA and FLO MXC compositions provided significantly reduced friction loop pressures than the FRACSOL alone.
  • the FLO MXA and FLO MXC compositions at 1/10 the concentration (0.5 L/m 3 ) provided comparable or slightly better results than the F-100 at about ten times the concentration (5 L/m 3 ); and significantly reduced friction loop pressures than the F-
  • both the 0.5 L/m 3 FLO MXA and FLO MXC compositions showed a comparable percent reduction in friction to F-100 at 5 L/m 3 when plotted verses Reynolds number. Additional testing showed that the 0.5 L/ m 3 of each of the FLO MXA and FLO MXC friction reducers gave the same results as when the concentrations of the FLO MXA and FLO MXC were increased to 1L/ m 3 to 5 L/ m 3 in FRACSOL.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Lubricants (AREA)
  • Epoxy Compounds (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

La présente invention concerne un procédé d'entretien de puits. Le procédé comprend la fourniture d'un fluide d'entretien de puits. Le fluide d'entretien de puits est formulé avec les composants suivants comprenant au moins un réducteur de frottement choisi parmi des polychloroprènes, des polymères d'acétate de vinyle, des polyoxydes d'alkylène et poly-alpha-oléfines ; et un fluide de support non aqueux. Le fluide d'entretien de puits est introduit dans le puits.
PCT/US2014/056817 2013-10-07 2014-09-22 Fluide d'entretien de puits contenant un gaz d'hydrocarbure comprimé WO2015053928A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
MX2016004038A MX2016004038A (es) 2013-10-07 2014-09-22 Fluido para servicio de pozo que contiene gas de hidrocarburo comprimido.
CN201480055477.8A CN105722943A (zh) 2013-10-07 2014-09-22 含有压缩的烃气体的修井流体

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US14/047,592 US20140034322A1 (en) 2010-08-13 2013-10-07 Well servicing fluid containing compressed hydrocarbon gas
US14/047,592 2013-10-07

Publications (1)

Publication Number Publication Date
WO2015053928A1 true WO2015053928A1 (fr) 2015-04-16

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PCT/US2014/056817 WO2015053928A1 (fr) 2013-10-07 2014-09-22 Fluide d'entretien de puits contenant un gaz d'hydrocarbure comprimé

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CN (1) CN105722943A (fr)
AR (1) AR097958A1 (fr)
MX (1) MX2016004038A (fr)
WO (1) WO2015053928A1 (fr)

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3692676A (en) * 1969-12-22 1972-09-19 Continental Oil Co Method of friction loss reduction in oleaginous fluids flowing through conduits
US6767869B2 (en) * 2000-02-29 2004-07-27 Bj Services Company Well service fluid and method of making and using the same
US20070265172A1 (en) * 2006-05-11 2007-11-15 Chevron Phillips Chemical Company Lp Wellbore servicing fluids comprising grafted homopolymers and methods of using same
US20120037371A1 (en) * 2010-08-13 2012-02-16 Gupta D V Satyanarayana Well Servicing Fluid
US8211834B2 (en) * 2008-07-25 2012-07-03 Calfrac Well Services Ltd. Hydrocarbon-based fracturing fluid compositions, methods of preparation and methods of use

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3692676A (en) * 1969-12-22 1972-09-19 Continental Oil Co Method of friction loss reduction in oleaginous fluids flowing through conduits
US6767869B2 (en) * 2000-02-29 2004-07-27 Bj Services Company Well service fluid and method of making and using the same
US20070265172A1 (en) * 2006-05-11 2007-11-15 Chevron Phillips Chemical Company Lp Wellbore servicing fluids comprising grafted homopolymers and methods of using same
US8211834B2 (en) * 2008-07-25 2012-07-03 Calfrac Well Services Ltd. Hydrocarbon-based fracturing fluid compositions, methods of preparation and methods of use
US20120037371A1 (en) * 2010-08-13 2012-02-16 Gupta D V Satyanarayana Well Servicing Fluid

Also Published As

Publication number Publication date
CN105722943A (zh) 2016-06-29
MX2016004038A (es) 2016-06-02
AR097958A1 (es) 2016-04-20

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