WO2011153466A2 - Système d'injection pour la récupération assistée du pétrole - Google Patents

Système d'injection pour la récupération assistée du pétrole Download PDF

Info

Publication number
WO2011153466A2
WO2011153466A2 PCT/US2011/039119 US2011039119W WO2011153466A2 WO 2011153466 A2 WO2011153466 A2 WO 2011153466A2 US 2011039119 W US2011039119 W US 2011039119W WO 2011153466 A2 WO2011153466 A2 WO 2011153466A2
Authority
WO
WIPO (PCT)
Prior art keywords
surfactant
injection
gas
liquid
injecting
Prior art date
Application number
PCT/US2011/039119
Other languages
English (en)
Other versions
WO2011153466A3 (fr
Inventor
Aaron W. Sanders
Terry A. Mann
Original Assignee
Dow Global Technologies Llc
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 Dow Global Technologies Llc filed Critical Dow Global Technologies Llc
Priority to CA2801571A priority Critical patent/CA2801571A1/fr
Publication of WO2011153466A2 publication Critical patent/WO2011153466A2/fr
Publication of WO2011153466A3 publication Critical patent/WO2011153466A3/fr

Links

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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/164—Injecting CO2 or carbonated water
    • 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
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/594—Compositions used in combination with injected gas, e.g. CO2 orcarbonated gas
    • 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
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P90/00—Enabling technologies with a potential contribution to greenhouse gas [GHG] emissions mitigation
    • Y02P90/70—Combining sequestration of CO2 and exploitation of hydrocarbons by injecting CO2 or carbonated water in oil wells

Definitions

  • the invention relates generally to mobile systems and methods for delivering additives to high pressure gas lines used in enhanced oil recovery (EOR). More specifically, the invention relates to mobile systems and methods for the dispensing of surfactant into high pressure C0 2 streams used for enhanced oil recovery applications.
  • EOR enhanced oil recovery
  • EOR Enhanced oil recovery
  • C0 2 injection is more popular due to high displacement efficiency of C0 2.
  • C0 2 has a low viscosity and suffers from poor conformance, mobility, and ultimately low sweep efficiency.
  • One method that has been developed to alleviate this problem is the use of surfactants to emulsify the supercritical C0 2 in water (brine) as an emulsion. This creates an apparent viscosity in the C0 2 and improves the mobility and conformance of the C0 2 as it propagates through the strata in an oil field.
  • W02008081048 which describes a system for another form of enhanced oil recovery, alkaline surfactant polymer (ASP) flooding.
  • ASP alkaline surfactant polymer
  • a new grinding apparatus for improving the dissolution time of the polymer is provided.
  • W02008071808 describes an entire system for implementing an ASP solution in the field.
  • W02007011812 describes a mobile unit for another method of EOR by nitrogen flooding. The unit is comprised of a nitrogen generating unit and a pumping system that can deliver the generated nitrogen to the wellbore. Further it teaches the pumping of other well fluids concurrently with the nitrogen.
  • US2004/034521 describes a three in one nitrogen, chemical, coiled tubing system on a mobile unit.
  • U.S. Patent No. 6702011 describes a mobile unit for delivery of nitrogen through coiled tubing.
  • an enhanced oil recovery apparatus for creating a wellbore fluid comprising supercritical C0 2 and a surfactant.
  • the apparatus comprises a storage tank for containing a surfactant which is injected into the C0 2 stream, a pump for delivering surfactant to the C0 2 stream, means for injecting the surfactant into the C0 2 stream, and a feedback control for maintaining a constant concentration of surfactant in the supercritical C0 2 stream.
  • a method of enhancing oil recovery by creating a wellbore fluid for injection into an oil field by a mobile enhanced oil recovery apparatus comprising a storage tank, means for injecting surfactant into the supercritical C0 2 stream, and a feedback control for maintaining a constant concentration of surfactant in the supercritical C0 2 stream.
  • the method comprises the steps of transmitting a surfactant to the injection pipe, injecting the surfactant into a supercritical C0 2 stream at a controlled rate, creating a wellbore fluid comprising the C0 2 and the surfactant, and injecting the wellbore fluid into the oil field.
  • the wellbore fluid comprises the surfactant and a gas.
  • the gas may be any number of gases commonly used for this purpose.
  • Supercritical carbon dioxide is used as an example in the specification. In this context it should also be understood that the carbon dioxide may also be liquefied.
  • the invention provides a mobile method of delivering additives into high pressure supercritical C0 2 streams that can be employed as needed in the field. More specifically the invention relates to a mobile unit encompassing one or more surfactant storage tanks, high pressure pumps, a feedback control system for maintaining the desired surfactant injection rate based on the flow rate of the C0 2 , a pressure relief system, heated surfactant storage, injection line and high pressure connection devices, and an electric generator, and fuel container.
  • the surfactant may be thermally treated up to the point at which it is injected into the stream of supercritical C0 2 .
  • Mobility is a great advantage to the claimed invention.
  • Numerous benefits are provided, for example, prior to deployment to a new injection well location, this equipment can be loaded with fuel and surfactant at a central storage facility then deployed for the desired length of time on the given well. This significantly reduces the cost of large scale implementation of equipment dedicated to each and every injection well, and it minimizes environmental risks by, for example, conducting fuel and surfactant replenishment at a central, fit for purpose transload facility.
  • Figures 1A through ID are schematic depictions of a method of injecting a wellbore fluid into an oil field in accordance with one embodiment of the invention.
  • Figure 2 is a schematic depiction of one embodiment of the invention depicted in Figure 1 as alternatively shown as a mobile unit.
  • Figure 3 is a graphical representation of the injection rate of C0 2 versus time, for two C0 2 injection cycles.
  • FIG. 1A through ID wherein all numbers designate like parts throughout several views of the invention there is shown one embodiment of a method of enhancing oil recovery by creating a wellbore fluid for injection into an oil field by a mobile enhanced oil recovery apparatus.
  • the apparatus comprises a storage tank 12, means for injecting fluid 14 into a gas stream, and a pump having a feedback control for maintaining a constant concentration of fluid in a gas stream 16, Fig. IB.
  • the apparatus may also comprise a fuel tank 20.
  • the various elements of the apparatus of the invention may be interconnected by any number of tubing and piping systems.
  • tubing, piping and hose may be used in accordance with the invention.
  • Inner diameters may range from less than an inch to two inches or greater.
  • the tubing, piping or hose may be heated or cooled as necessary to prepare the surfactant for injection.
  • the method comprises the steps of injecting a surfactant into a supercritical C0 2 stream at a controlled rate creating a wellbore fluid comprising the supercritical C0 2 and surfactant and injecting the fluid into the oil field.
  • the invention comprises one or more containment vessels 12, Figure 1A.
  • the function of the container is to store surfactant.
  • the container may also function to provide a site for processing the surfactant. Processing in this context means heating, cooling, agitating, pressurizing, etc.
  • the containers may also be used as a site for the addition of any other constituents which may be desired to be intermixed with the surfactant.
  • the container may take any number of shapes and sizes. Some considerations which are relevant to the size and shape of the containment vessel include transportability, discharge and refill, material of construction, pressure relief protection, the overall function of the tank (containment and/or mixing), and the necessity for thermal processing among other factors.
  • the size and shape of the vessel may also be determined by the use level of surfactant at the site of injection.
  • vessels ranging in size from about 300 gallons to 36,000 gallons have been contemplated for use.
  • containers of the size of about 500 to 6,000 gallons have been found most desirable.
  • Containment vessels which provide agitation (stirring), heating and/or cooling may also be useful in accordance with the invention.
  • Heating may be conducted through use of resistance elements.
  • closed loop heating and cooling systems may be used for circulating coolant/refrigerants or heating fluids.
  • Containment vessels which are preferred include portable containers that may be on and off loaded from any number of wheeled vehicles including flat bed trailers and railcars, Figure 2. These types of containers are widely regarded as "isotainers" and can take any number of shapes, styles, and sizes.
  • the invention comprises a surfactant injection system 14, Figure 1C.
  • the surfactant injection system comprises an injection quill.
  • the purpose of the injection quill is to facilitate mixing between the two process fluids, in this case surfactant and supercritical C0 2 , delivered by the main header pipe and the quill.
  • the quill generally injects surfactant at the center of the main header pipe in the form of a solid jet or spray. This processing of fluids (such as gases and/or supercritical liquids) allows the scC0 2 and surfactant to mix thoroughly.
  • quills useful in the invention are those commercially available from any number of known sources.
  • Materials used in the manufacture of quills tend to be alloys such as high alloy steel, carbon steel and stainless steel including Iconel ® , Incolloy ® , and Hastelloy ® .
  • Relevant considerations in choosing quills of any different material include corrosion resistance, thermal properties, acid resistance, flame resistance and overall strength. Material to these concerns are the types of fluids to be dispensed and the rate at which these fluids are dispensed from the quill.
  • Quills which have been found useful in accordance with the invention include Kenco Injectors such as models KINJ, and KINJM.
  • the fluid velocity should be less than that which will damage the quill.
  • fluid velocity in a 2" line should remain below 900 gals/min (assuming a 3" length from thread to tip).
  • a common set of injection well parameters includes about 7000 bpd water in a 2" line with a flow rate of about 204 gals/min. With 20 MMscfd of C0 2 in a 2" line, the flow rate is about 200 gals/min.
  • An exemplary surfactant injection rate through a Kenco injector is about 240 gph.
  • the quantity of surfactant injected will be approximately 13 gph.
  • the quill may be installed in relationship to the main header pipe in any number of fashions.
  • the quill is installed in the first 1 ⁇ 2 inch tie point upstream of the wellhead, prior to any flowline disruptions such as inline screens or inline chokes.
  • quills such as Kenco KINJ-50 (1/2" NPT), -S6 (316 SS Steel), -L2 (2" length) and Kenco KINJ- S6-L3 have been found useful at this location.
  • the quill length with a tip that most closely centers in the header pipe is preferred.
  • the preferred quill is installed with a preferred orientation with the longest side of the quill upstream and with the quill tip at the center of the C0 2 line.
  • the quill is used to mix surfactant with supercritical C0 2 .
  • the quill may be positioned in accordance with the invention in any number of configurations.
  • the quill may be positioned proximate the well head to inject surfactant into the supercritical C0 2 as close as possible to the wellhead.
  • the quill may be positioned up stream from the wellhead, causing additional mixing of the surfactant with supercritical C0 2 well before the mixture enters the production/injection tubing.
  • quills can be installed, either permanently or temporarily, at each well and can be connected to the pumping system when required. The quill does not need to be transported with the truck. In instances where more than one well is fed by a single tank 12, multiple lines may be used through multiple quills 14.
  • an embodiment of the mobile EOR apparatus which comprises a surfactant flow controller 16.
  • the surfactant flow controller 16 functions to monitor and maintain the flow of the surfactant into the supercritical C0 2 .
  • Flow of the supercritical C0 2 may vary or otherwise occur at an intermittent rate. Accordingly, to provide a wellbore fluid having a constant concentration of surfactant and supercritical C0 2 for permeating the oil field strata, the flow rate of the surfactant injected into the supercritical C0 2 need also be varied accordingly. Any number of devices may be used which provide this function.
  • Typical devices monitor surfactant flow rates in parts per million of flow rate and allow manual or automatic entry of set points. Any variety of flow meters may be used with the invention.
  • the surfactant injection flow meters require a C0 2 flowrate signal from the supercritical C0 2 header in order to ratio the surfactant in the proper concentration to the varying rate of supercritical C0 2 being delivered to the well.
  • the calibration procedure for such a unit is known to those of skill in the art.
  • the surfactant flow rate will be dependent upon the supercritical C0 2 flow rate.
  • Two useful flow controllers are those produced and sold by Baker Hughes under the Sentry II and Sentry Net 3 trademarks.
  • the invention also comprises a pump 16 and a source of power such as a generator 18, Figure ID.
  • a source of power such as a generator 18, Figure ID.
  • Any type of pump may be used which is capable of providing pressure ranging from about 1000 psi to 3500 psi.
  • the power source powers the surfactant injection pumps injecting the surfactant into the gas stream through the quill.
  • Any type of generator may be used depending upon portability, power requirements, refueling, and running time, among other factors.
  • One generator which has been found useful is the 36 KW diesel powered generator made by Mulitquip Inc (supplied by Carrier). When fueled this generator weighs over 4000 lbs and consumes fuel at 2.7 gph @ 100% prime.
  • a generator such as this usually has an internal fuel tank and may be provided with an auxiliary tank for less frequent resupply. In operation, the generator may provide from about 240 volts to about 480 volts at currents ranging from about 108 amps to 54 amps.
  • a surfactant be added to the supercritical carbon dioxide to generate a foam in the formation.
  • a foam can generate an apparent viscosity of about 100 to about 1,000 times that of the injected gas. Therefore, the foam can inhibit the flow of the supercritical C0 2 into that portion of the oil reservoir that has previously been swept.
  • the foam can serve to reduce the tendency for the supercritical C0 2 to channel through highly permeable flissures, cracks, or strata, and direct it toward previously unswept portions of the subterranean formation. As such, the foam can force the supercritical C0 2 to drive the recoverable hydrocarbons from the less depleted portions of the reservoir toward the production well.
  • Nonionic surfactants are usually organic compounds that are amphiphilic, meaning they contain both hydrophobic groups (alkylated phenol derivatives, fatty acids, long-chain linear alcohols, etc.) and hydrophilic groups (generally ethylene oxide, propylene oxide and/or butylenes oxide chains of various lengths), therefore they can be soluble in both organic solvents (non-polar) and polar solvents such as water.
  • the nonionic surfactants useful in the invention can lower the interfacial tension between carbon dioxide (such as carbon dioxide in a supercritical state) and water.
  • Nonionic surfactants are capable of dissolving in scC0 2 in dilute concentrations, where they can help to stabilize carbon dioxide-in-water emulsions and/or foams (referred to herein as "foam”), discussed herein.
  • nonionic surfactants for the present disclosure include, but are not limited to, branched alkyphenol alkoxylates, linear alkylphenol alkoxylates, and branched alkyl alkoxylates. Specific examples of such nonionic surfactants can be found in "C0 2 -Souble Surfactants for Improved Moblity Control" authored by Xing et al. (Society of Petroleum Engineers, SPE 129907, presented at the 2010 SPE Improved Oil Recovery Symposium, Tulsa OK, 24-28 April 2010), which is incorporated herein by reference in its entirety.
  • examples of surfactants useful with the present disclosure can also be found in U.S. Pat. Nos. 6,686,438 to Beckman and 5,789,505 to Wilkinson, and the U.S. Pat. Application entitled “Compositions for Oil Recovery and Methods of Their Use,” U.S. Pat. Application Serial No. 61/196,235, which are incorporated herein by reference.
  • this surfactant may be stored at the site of use in a containment vessel 12.
  • the surfactant may be in solution ranging in concentration from about 40 wt-% to 100 wt-%.
  • any number of diluents may be used to protect the surfactant from freezing. If an appropriate diluent is not used for the ambient conditions, it may be necessary to provide auxiliary heating to the surfactant storage vessel and any lines through which the surfactant flows to avoid freezing.
  • diluents may be used to adjust the freeze point of the surfactants to range from about -40°F to 50°F.
  • the rate of injection of the surfactant into the scC0 2 stream may vary, generally, surfactant is injected into the scC0 2 stream at a rate creating a concentration of liquid (surfactant) in the wellbore fluid ranging from about 100 to 5,000 ppm.
  • the injection system that will be utilized will be flexible in its surfactant volume capability. It should be designed to pump surfactant in varying concentrations to allow for reservoir respouse. In one example, at the minimum expected C0 2 rate of 7MMscfd, up to 3 times the recommended surfactant concentration can be delivered.
  • the table lists the gallon per hour rates that need to be delivered to the C02 stream to maintain the desired concentration in ppm.
  • the maximum C02 flow rate of the injection well as well as the expected minimum rate will determine the range of pump rates necessary.
  • the C02 rate is determined based on standard temperature and pressure, and the surfactant concentration may need to be adjusted for diluents. This table is an example and other flow rates and concentrations are not excluded.
  • New location injection rates range from 12MM - 18MM/day. Plan for 10% more worse case yields up to 20MM/day.
  • the lower line shows the effect of the foam/emulsion surfactant in accordance with the inventions.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Organic Chemistry (AREA)
  • Materials Engineering (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Fats And Perfumes (AREA)

Abstract

La présente invention concerne un procédé d'assistance à la récupération du pétrole par la fourniture d'un système mobile d'injection de tensioactifs comportant un réservoir de stockage, des moyens pour l'injection de tensioactifs dans un flux de CO2 supercritique, et une commande à réaction pour maintenir une concentration constante de tensioactifs dans un flux gazeux. Le procédé comprend les étapes suivantes: la création d'un fluide comportant le tensioactif et le gaz d'injection, et l'injection du fluide dans les couches du champ pétrolifère.
PCT/US2011/039119 2010-06-04 2011-06-03 Système d'injection pour la récupération assistée du pétrole WO2011153466A2 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CA2801571A CA2801571A1 (fr) 2010-06-04 2011-06-03 Systeme d'injection pour la recuperation assistee du petrole

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US35150610P 2010-06-04 2010-06-04
US61/351,506 2010-06-04

Publications (2)

Publication Number Publication Date
WO2011153466A2 true WO2011153466A2 (fr) 2011-12-08
WO2011153466A3 WO2011153466A3 (fr) 2012-01-26

Family

ID=44627265

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2011/039119 WO2011153466A2 (fr) 2010-06-04 2011-06-03 Système d'injection pour la récupération assistée du pétrole

Country Status (2)

Country Link
CA (1) CA2801571A1 (fr)
WO (1) WO2011153466A2 (fr)

Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5789505A (en) 1997-08-14 1998-08-04 Air Products And Chemicals, Inc. Surfactants for use in liquid/supercritical CO2
US6686438B1 (en) 1999-09-24 2004-02-03 University Of Pittsburgh Carbon dioxide-philic compounds and methods of synthesis thereof
US20040034521A1 (en) 2000-10-13 2004-02-19 Yasushi Kawakura Data relay system, data relay method, data relay program, information processing method, and information processing program
US6702011B2 (en) 2002-04-22 2004-03-09 James B. Crawford Combined nitrogen treatment system and coiled tubing system in one tractor/trailer apparatus
WO2007011812A1 (fr) 2005-07-16 2007-01-25 P.E.T. International, Inc. Systeme de generation d'azote combine et systeme de fluide de service de puits regroupes en un seuil appareil d'unite d'alimentation
WO2008071808A1 (fr) 2007-10-12 2008-06-19 S.P.C.M. Sa Installation de récupération assistée du pétrole à l'aide de polymères solubles dans l'eau et procédé d'exploitation
WO2008081048A2 (fr) 2007-10-12 2008-07-10 S.P.C.M. Sa Installation de recuperation d'huile amelioree au moyen de polymeres hydrosolubles et procede d'utilisation associe

Family Cites Families (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4763730A (en) * 1986-08-11 1988-08-16 Chevron Research Company Miscible gas enhanced oil recovery method using oil-brine compatible pre-formed foam
US5358046A (en) * 1993-01-07 1994-10-25 Marathon Oil Company Oil recovery process utilizing a supercritical carbon dioxide emulsion
CA2243105C (fr) * 1998-07-10 2001-11-13 Igor J. Mokrys Exploitation de gisements d'hydrocarbures sous pression elevee par injection de vapeur
US7694731B2 (en) * 2006-02-13 2010-04-13 Team Co2, Inc. Truck-mounted pumping system for treating a subterranean formation via a well with a mixture of liquids
JP5163996B2 (ja) * 2007-07-06 2013-03-13 小出 仁 液化炭酸ガスの地中送り込み方法及びその地中送り込み装置
WO2010044818A1 (fr) * 2008-10-15 2010-04-22 Dow Global Technologies Inc. Compositions pour la récupération de pétrole et procédés d'utilisation de ces compositions

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5789505A (en) 1997-08-14 1998-08-04 Air Products And Chemicals, Inc. Surfactants for use in liquid/supercritical CO2
US6686438B1 (en) 1999-09-24 2004-02-03 University Of Pittsburgh Carbon dioxide-philic compounds and methods of synthesis thereof
US20040034521A1 (en) 2000-10-13 2004-02-19 Yasushi Kawakura Data relay system, data relay method, data relay program, information processing method, and information processing program
US6702011B2 (en) 2002-04-22 2004-03-09 James B. Crawford Combined nitrogen treatment system and coiled tubing system in one tractor/trailer apparatus
WO2007011812A1 (fr) 2005-07-16 2007-01-25 P.E.T. International, Inc. Systeme de generation d'azote combine et systeme de fluide de service de puits regroupes en un seuil appareil d'unite d'alimentation
WO2008071808A1 (fr) 2007-10-12 2008-06-19 S.P.C.M. Sa Installation de récupération assistée du pétrole à l'aide de polymères solubles dans l'eau et procédé d'exploitation
WO2008081048A2 (fr) 2007-10-12 2008-07-10 S.P.C.M. Sa Installation de recuperation d'huile amelioree au moyen de polymeres hydrosolubles et procede d'utilisation associe

Also Published As

Publication number Publication date
CA2801571A1 (fr) 2011-12-08
WO2011153466A3 (fr) 2012-01-26

Similar Documents

Publication Publication Date Title
US9458707B2 (en) Injection system for enhanced oil recovery
US9796910B2 (en) Fracturing system and method for an underground formation using natural gas and an inert purging fluid
CA2773019C (fr) Methode et appareil pour preparer les fluides de fracturation
US8312924B2 (en) Method and apparatus to treat a well with high energy density fluid
NZ571162A (en) Liquified petroleum gas fracturing system including the use of inert gas to purge components
US8522875B2 (en) Hydrocarbon-based fracturing fluid compositions, methods of preparation and methods of use
US9656221B2 (en) Systems and methods for treating fluids
CN105713592B (zh) 用于制备并供应高质量压裂液的方法
WO2011153466A2 (fr) Système d'injection pour la récupération assistée du pétrole
CA3043154C (fr) Procedes et systemes de fracturation hydraulique utilisant un melange gazeux
US20200291761A1 (en) Unique chemical delivery method for stimulating production in oil and gas wells
CA2662811C (fr) Compositions de fluides de fracturation hydrocarbones, methodes de preparation et d'utilisation

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 11726577

Country of ref document: EP

Kind code of ref document: A2

ENP Entry into the national phase in:

Ref document number: 2801571

Country of ref document: CA

NENP Non-entry into the national phase in:

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 11726577

Country of ref document: EP

Kind code of ref document: A2