EP2496659A1 - Fluide d'injection et procede de recuperation assistee de petrole - Google Patents
Fluide d'injection et procede de recuperation assistee de petroleInfo
- Publication number
- EP2496659A1 EP2496659A1 EP10787501A EP10787501A EP2496659A1 EP 2496659 A1 EP2496659 A1 EP 2496659A1 EP 10787501 A EP10787501 A EP 10787501A EP 10787501 A EP10787501 A EP 10787501A EP 2496659 A1 EP2496659 A1 EP 2496659A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- guar
- sodium
- galactomannan polymer
- injection
- injection fluid
- 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.)
- Withdrawn
Links
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
- C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
- C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
Definitions
- the present invention relates to the field of enhanced oil recovery. More specifically, it relates to an injection fluid comprising at least one aqueous galactomannan polymer and an assisted recovery process using said injection fluid.
- Enhanced recovery of crude oil in a rock formation usually occurs in several stages.
- the first phase of production results from the natural energy of the oil in place, which flows freely due to the pressure difference between the deposit and the atmospheric pressure to a producing well from which it is pumped.
- This initial recovery called primary recovery, generally represents 5 to 20% of the average amount of oil in the rock formation.
- Secondary and tertiary recovery methods involve the use of several wells drilled around the depleted rock formation. At least one of the drilled wells is used to inject under pressure into the underground formation an injection fluid, it is called injection wells.
- the injection fluid forms a migration front which flows from the injection well to the production well (s).
- Enhanced Oil Recovery Due to its properties of immiscibility with oil, the injection fluid pushes the oil to the production wells. This technique is called Enhanced Oil Recovery (EOR) and it generally allows for the recovery of 25 to 75% of the oil involved.
- EOR Enhanced Oil Recovery
- Tertiary recovery differs from secondary recovery by composition of the injected fluid.
- secondary recovery is injected an aqueous liquid such as brine or fresh water from a well, while in the context of the tertiary recovery, additives were mixed with the fluid of aqueous injection prior to steps injection.
- the surfactants are used as addition compounds to lower the interfacial tension of the aqueous fluid and to allow this fluid to form emulsions and / or microemulsions with the oil present in the deposit.
- the formation of mixtures and / or microemulsions causes the displacement of oil trapped in the rock formations by reducing the interfacial tension and by solubilization of the oil in this fluid, increasing the recovery of oil present in underground formations.
- surfactant fluids have a lower viscosity than oil, resulting in limited efficiency in moving oil out of formations.
- Synthetic polymers are used to increase the viscosity of aqueous fluids. They improve the oil sweep by the injection fluid. These polymers are, for example, polyacrylamide, polyvinylpyrrolidone or polyvinyl sulphonate and their derivatives. Natural polymers such as polysaccharides extracted from seeds such as guar gum or algae such as alginates or caragens, or biopolymers produced by fermentation initiated by bacteria or fungi, are used for their high viscosity capacity (HYDROCOLLOIDS , CEH Marketing Research Report, Ray K. Wiil, October 2007).
- Natural polysaccharides are usually difficult to inject due to the presence of synthetic residues or weakly solvated portions of the chain may affect the permeability of the area surrounding the injection well.
- the object of the present invention is to overcome this disadvantage of the prior art.
- the object of the invention is therefore to propose a new injection fluid intended for enhanced oil recovery operations and having good injectivity properties.
- the invention also relates to an injection fluid having a moderate adsorption on the formation.
- the invention further relates to a novel injection fluid having a high resistance to mechanical damage.
- the subject of the present invention is an injection fluid having good properties of thermal stability.
- the invention thus provides an aqueous injection fluid for enhanced oil recovery processes comprising at least one galactomannan polymer substituted with at least one sulfonating agent.
- the invention also relates to a method for enhanced oil recovery comprising the following steps: a) injecting an aqueous injection fluid into an underground oil formation via one or more injection wells; displaces the aqueous injection fluid within the formation towards one or more production wells, c) recovering the oil through one or more production wells.
- said aqueous injection fluid comprising at least one galactomannan polymer substituted with at least one sulfonating agent.
- enhanced oil recovery refers to the process generally involving the injection of an aqueous fluid or injection fluid of a given type into a deposit or subterranean formation ( e).
- the injected fluids and injection processes complement the natural energy present in the deposit to move the oil to a production well.
- injected fluids interact with reservoir rock and oil to create favorable conditions for movement for recovery.
- underground formation or “underground gisem ⁇ nt” as used herein refers to a place where the crude hydrocarbons found in the deposits are formed within the earth's crust. Such training can be anywhere between 50m and 10,000m below the surface, and can be of various shapes, sizes and ages.
- injection fluid or “injection solution” as used herein refers to an aqueous fluid used for the enhanced recovery of oil in an underground formation. This fluid does not damage the underground formation.
- One aspect of the present invention relates to a method for recovering oil present in a deposit or an underground formation (e) by injecting into this deposit or formation an injection fluid comprising at least one galactomannan polymer.
- FIG. 1A represents the structure of a non-derivative guar
- FIG. 1B is a schematic representation of a non-derivative galactomannan polymer
- FIG. 1C represents the structure of a hydroxypropyl guar (HP guar)
- Figure 3A shows light scattering (Y-axis), measured as a function of elution time (X-axis).
- FIG. 3B shows the refractive index (Y axis), measured as a function of the elution time (X axis),
- FIG. 4 shows the injectivity properties of the galactomannan polymers according to the invention. It groups the pressure (Y axis, in mbar) induced by the flow of different polymers of galactomannan (X axis, volume injected in ml). Three galactomannan polymers with different degrees of substitution were tested against unsulfonated hydroxypropyl guar (guar HP),
- FIG. 5 represents the adsorption isotherms of the HP guar according to the invention with Speswhite TM in synthetic seawater.
- HP guar and acrylamide polymer were used for comparison.
- the Y axis represents the adsorbed polymer in mg / g and the X axis the equilibrium concentration of the polymer in mg / l.
- the black circles represent the HP guar
- the crosses represent the hydrolysed polyacrylamide HPAM
- the relative viscosity (Y-axis) is measured at various increasing shear rates (X-axis, in s -1 ).
- unsheared HP guar - SVS / DS 1, 57
- the mobility reduction was measured according to the volume of sample injected (X axis, in cm 3 ).
- Galactomannan polymers are polysaccharides consisting essentially of galactose and mannose units; they are usually found in the seed endosperm. legumes, such as guar, carob seeds, carob honey, flamboyant and others, or in microbial sources, especially yeasts and fungi.
- the galactomannan polymers are distinguished from each other by their mannose / galactose (Man / Gal) molar ratio and by their molecular weight.
- Guar flour for example, is mainly composed of a galactomannan which is essentially a straight chain of mannose with single-patterned galactose branches.
- the mannose units are linked by (1-4) beta-glycosidic linkages and the galactose branching is effected by means of a (1-6) alpha-glycosidic linkage on alternate mannose units.
- the galactose / mannose ratio in the guar polymer is therefore equal to two.
- the guar from Cyamopsis tetragonalobus has a high molecular weight (about 3 million g / mol).
- the Man / Gal ratio of different Galactomannan polymers isolated from different seeds are shown in Table 1 (Manjoosha Srivaxtava, Kapoor VP, Chemistry & Biodiversity, Vol.2, 295-317, (2005)).
- the structure of the galactomannan guar is shown in Figure 1A and a schematic structure of a galactomannan polymer is shown in Figure 1B.
- Table 1 List of principal galactomannan polymers derived from seeds
- the galactomannan polymers can be used either in the natural state (i.e., a pure guar polymer), or derivatives.
- the galactomannan polymers derived may be chosen from the group consisting of the following guars: hydroxypropyl guar (guar HP), guar carboxymethyl (guar CM), guar carboxymethyl hydroxypropyl (guar MHCP), guar hydroxyethyl (guar HE), guar carboxymethyl hydroxyethyl (guar MHC), guar hydroxypropyl guar hydrophobically modified cationic guar (cationic guar HMHP), hydrophobically modified carboxymethylhydroxypropyl guar (guar HMCMHP) and hydrophobically modified cationic guar (cationic guar HM).
- hydroxypropyl guar is marketed by Rhodia Inc. as Jaguar® 8012, Jaguar® 8060, Jaguar® 8000, Jaguar® HP-20 and Jaguar® HP-23.
- the galactomannan polymer is hydroxypropyl guar (FIG. 1C).
- the galactomannan polymer is hydroxyethyl guar.
- the galactomannan polymers or the derived galactomannan polymers usually have a molecular weight of between 100,000 and 20,000,000 g / mol, preferably between 500,000 and 15,000,000 g / mol, more preferably between 1,000,000 and 10,000. 000 g / mol, according to their degree of polymerization.
- the molecular weight of the galactomannan polymers is determined by gel permeation chromatography (GPC), coupled to a multi-angle DDL detector (MALLS). This technique gives absolute weight values based on the known molecular weight of an external calibration standard.
- the molecular weight of the galactomannan polymer is in fact the weight-average molecular weight obtained by GPC.
- the invention can be applied to any galactomannan polymer or galactomannan polymer derivative.
- the sulfonation of polysaccharides in general and guar in particular can be achieved in many ways, all known to those skilled in the art.
- the reaction of a galactomannan polymer with sultones can be carried out as described in US-2006 / 0.151.172.
- the galactomannan polymers can also be pre-functionalized before reacting with a sulfonating agent.
- the galactomannan polymers can be pre-functionalized with double bonds using allyl and glycidyl ether or allyl bromide.
- the pre-functionalized galactomannan polymers react either with sodium bisulfite, as taught in document US-2008 / 0.300.149, or with sodium sulphite according to document US-2007 / 0.015.678, in order to to obtain the sulfonation of the galactomannan polymer according to the invention.
- Another way of sulphonating galactomannan is to graft a sulphonating agent by radical polymerization or by addition of Michael, for example. Such reactions are described in US-5,378,830, US-2008/020948 and US-2008/021167.
- the degree of sulfonation of the galactomannan polymers can be varied by varying the reaction conditions (e.g., sulfonating agent, reaction time, reaction temperature) .
- Any sulphonate group-containing sulphonating agent can be used to produce the sulphonated galactomannan polymer according to the present invention.
- the sulfonating agent is selected from the group consisting of: 2-acrylamido-2-methylpropanesulfonic acid (AMPS), sodium vinylsulfonate (SVS), sodium (meth) allyl sulfonate, sulfonated styrene, (meth) allyloxybenzene acid sulfonic acid, sulfonate 1-allyloxy 2-hydroxypropyl sodium, sodium chlorohydroxypropanesulfonate (CHPSNa), sodium bisulfite, cyclic sultone (such as 1,3-propylsultone or 1,4-butylsultone), sodium styrene sulfonate (SSS).
- AMPS 2-acrylamido-2-methylpropanesulfonic acid
- SVS sodium vinylsulfonate
- the sulphonating agent is 2-acrylamido-2-methylpropanesulphonic acid or sodium chlorohydroxypropanesulphonate.
- the sulfonating agent is sodium vinyl sulfonate (SVS).
- degree of substitution means the average substitution of sulfonating agent per anhydro sugar unit in the galactomannan polymer.
- the DS varies between 0 and 3.
- a DS 1 means that, on average, 1 sulphonated group has been grafted per sugar cycle, whereas 2 initial 3 hydroxyls are still intact.
- a DS 3 means that, on average, 3 sulphonated groups were grafted per sugar ring, that is to say that no free hydroxyl remains.
- the present invention therefore provides a galactomannan polymer having degree of substitution (DS) values between 0.2 and 3. According to a preferred embodiment, the DS values are between 0.25 and 2.5 and preferably between 0.5 and 2.2.
- the concentration of the galactomannan polymer in the injection fluid is between 0.5 and 5 g / l. According to a preferred embodiment, the concentration varies between 0.7 and 3 g / l.
- the component of the injection fluid having the highest concentration is water.
- the water will be predominantly present in the fluid in percent by weight.
- Water is typically present in a weight ratio of about 50% or more, more typically about 80% or more by weight of fluid.
- Water can come from n any source provided that the source does not contain impurities chemically or physically incompatible with the other components of the fluid (eg causing undesirable precipitation).
- the water does not need to be potable, it can be brackish and contain metal salts such as sodium, potassium, calcium, zinc, magnesium, etc., or other materials typical of water sources encountered in or near oil fields.
- the injection fluid may optionally contain a gas such as air, nitrogen or carbon dioxide, so as to have a fluid or an energetic foam.
- the injection fluid may contain any of the conventional chemicals found in such fluids, such as anti-corrosion additives, oxygen scavengers, scale inhibitors or any other type of deposit inhibitor, salts, soda or other base, acids, surfactants, etc.
- the method according to the present invention may optionally be preceded by a hydraulic fracturing step.
- a fracturing fluid such as water is injected into a well and towards the face of the formation at a pressure and a flow rate sufficient to overcome the cover pressure of the formation, and initiate the creation and / or extension of a fracture in the formation.
- Example 1 Example galactomannan polymer synthesis substituted according to the invention
- the grafting of the sulfonating agent onto the guar polysaccharide is carried out using methods known in the polysaccharide industry.
- One of the ways which can be implemented is to graft the sulfonating agent onto a hydroxypropyl guar (guar HP) using a water / alcohol dispersion process.
- the reaction medium is then heated to 60 ° C. The temperature is maintained for 4 hours, then the reactor is cooled to room temperature.
- the suspension thus obtained is filtered by means of a ceramic filter.
- the paste obtained is redispersed in 500 ml of isopropanol / water 80/20 vol / vol. Acetic acid is then added to this suspension to neutralize the product. This suspension is then filtered.
- the finally obtained paste is washed twice with 500 ml of isopropanol / water 80/20 vol / vol, then the paste is dried at room temperature and ground.
- the concentrated solution of SVS is obtained without prior preparation from a solution of SVS 25% (Proviron supplied) heated in a rotary evaporator so as to have a final concentration equal to 44.9%.
- Jaguar® HP105 has an average of 0.6 hydroxyl groups per saccharide unit. The characteristics of the synthesized compound have been studied. The degree of substitution is measured by 13C-NMR quantitative analysis according to the following protocol:
- TFA trifluoroacetic acid
- the typical process of guar cleavage is as follows: 1 gram of guar is dispersed in 4 ml of a 1: 1 solution of D20: TFA in a reaction vial. The flask is then heated at 90 ° C for at least 2 hours. Alternatively, the cleavage of the polymer chains can also be carried out by means of a microwave at 80 ° C for about 1 hour. The sample is then filtered and placed in a 10 mm NMR tube for quantitative carbon analysis. The optimal pulse width (pw) and the relaxation time (dl) are first measured, and the 13C is then quantitatively analyzed. The results obtained with a Varian Unitylnova of 400 MHz are presented in FIG. 2.
- the degree of substitution is calculated from the intensity of carbons resulting from sulphonated group grafts and the intensity of the anomeric carbons, both measured by 13C NMR.
- One of the two carbons belonging to the sulphonated grafts usually appears at about 50-54 ppm, whereas the anomeric carbons usually appear around 95-105 ppm.
- the degree of substitution is obtained by dividing the intensity of the peak belonging to the sulphonated grafts by the intensity of the anomeric carbon.
- the average molecular weights are measured by multiangle laser light scattering (MALLS) coupled to a gel permeate chromatography column. The protocol is described below: Column: Pheneomenex Polysep-GFC P5000 e ⁇ P4000 in series
- the samples are dissolved in the mobile phase at 0.1% by weight and filtered using PVDF filters of 0.45 ⁇ before injection.
- the MALLS detector is calibrated using 32 500 Da polyethylene oxide.
- Figure 3A shows the signal from the light scattering detector and Figure 3B shows the signal from the refractive index detector.
- the X axis represents the elution time which corresponds to the time required for the polymer chains to leave the size exclusion chromatography column.
- the weight-average molecular weight obtained for guar HP-SVS / DS 1.42 is 2300000 g / mol.
- the study of the injectivity properties of the galactomannan polymers according to the invention is carried out by measuring the loss of charge induced by the flow (constant flow) through a porous membrane (pores of 5 ⁇ ) as a function of the injected volume. .
- the injectivity is directly correlated to the increase of the pressure drop, a clogging of the porous medium resulting in a large increase in this pressure drop.
- the results are shown in Table 4.
- the pressure remains constant, which indicates the absence of clogging of the porous medium.
- the injectivity of the sulfonated samples obtained with this technique is comparable to that of the high molecular weight polyacrylamides, considered as the reference for applications in enhanced oil recovery.
- PPCO ethylene-propylene block copolymer
- the sample is mixed for 15 minutes at 700 rpm using a magnetic stirrer.
- An equivalent volume of polymer solution is introduced into the tube.
- the mixture is stirred for 24 hours at 700 rpm. All these steps are performed at room temperature.
- the clay is then separated from the solution by centrifugation (13,000 rpm for 1 hour).
- the amount of adsorbed polymer is determined from the difference between the concentration of the polymers in the supernatant before and after contact. It is measured using a total organic carbon analyzer (Shimadzu TOC 5050). By comparison, a conventional hydrolyzed polyacrylamide is used.
- FLOPAAM 3630S (VE4327, SNF Floerger) (referred to as HPAM or HPAM 3630S in the rest of the description).
- KCl 0.8 g / l
- - CaC, 2H 2 O 1.6 g / l
- NaN3 (bactericidal) 0.4 g / l.
- the brine is filtered using Millipore TM 0.22 ⁇ membranes and then used as a solvent for the guar polymers and for the HPAM.
- the solid / liquid ratio (S / L) is defined as the amount of clay expressed in mg per 100 ml of solution. Its value has a great influence on the experimental results: if it is too low, the adsorption may be difficult to determine by lack of sensitivity (at least 10% of polymers must be adsorbed),
- the S / L ratio is set at 1%.
- the moving fluids are subjected to high elongation flows and shear rates, particularly within the injection devices, chokes, valves and pumps.
- macromolecules can degrade and lose their ability to thicken. This is why the evaluation of a polymer includes its ability to withstand mechanical stresses.
- the resulting shear degradation for the polymer solution is evaluated by measuring its viscosity at 25 ° C, before and after the shear test, with a standard viscometer (Contraves LS 30).
- the concentration of HP-SVS guar and HPAM is 1.5 g / mol.
- the first polymer is a standard HP guar.
- the second polymer is a sulfonated guar HP (guar HP-SVS) having a degree of substitution of 1.57.
- guar HP-SVS sulfonated guar HP
- the solvent used to prepare the polymer solutions is synthetic seawater.
- the composition of the synthetic seawater is identical to that described above.
- the brine is filtered using Millipore TM MF membranes 0.22 ⁇ , then degassed under vacuum and placed under helium to prevent the formation of bubbles in the porous medium during core injection tests. These tests are carried out at 50 ° C.
- the carrot used is a natural Clashach sandstone.
- the outcrop rocks consist of homogeneous core samples cut from the same block of sandstone. Small cores are taken from the sample, then dried and placed in a viton sleeve (thickness 5 mm), then placed in a Hassler cell. These small carrots have a diameter of 4 cm and a length of between 6 and 7 cm.
- the sleeve is maintained under a nitrogen blanket pressure of 3000 kPa to ensure the lateral sealing of the core.
- the pore pressure is set at 2 bars by means of a counter-pressure valve at the cell outlet.
- the core is washed with several volumes of brine (seawater) injected into the pores and the permeability is determined at different flow rates.
- the carrot holder is placed in a thermostatically controlled oven at 50 ° C.
- a titanium capillary is arranged in line to determine the volume viscosities of the polymer solutions, both upstream and downstream of the core (through a bypass), which allowed for adsorption measurements. by material balance.
- Constant flow pumps (Pharmacia® P500, Labotron, Quizix) are used to inject either water or polymer solutions.
- Highly accurate and high sensitivity differential transducers (15, 75, 300, 900 mbar and 18 bar, full scale, 0.2% accuracy) can be used to monitor the reduction of mobility or permeability in carrots , as well as the viscosity of the polymers by the measurement of pressure losses through the capillary in line.
- Fraction collector is placed at the outlet of the device, downstream of the constant pressure valve, to perform complementary viscosity measurements (low shear).
- the adsorption measurements require the injection of relatively dilute polymer solutions in order to obtain good accuracy between the two fronts (steps 3 and 5).
- the reduction in mobility Rm measures the apparent viscosity of the polymer solution flowing in the medium. It takes into account both the viscosity of the chemical system and the reduction of permeability due to adsorption. It is related to the pressure drop using the following equation:
- APpoiymer is the pressure drop during the flow of the polymer in the core
- APbrine is the pressure drop during the flow of the brine before the injection of the chemical system.
- AP p0 i ymer and AP brine are determined at the same flow rate.
- Rm is also called RF resistance factor.
- Rk w is also called residual resistance factor RRF W.
- the reduction in mobility Rm x increases to about 4.1 (after injection into the pores of a PV volume of 1.5), the viscosity of the effluent reaching 100% of the viscosity of the injected solution after injection of a PV volume of about 1.8 (27.8 cm 3 ).
- Reduced mobility increases to approximately 4.15 (after injection into pores with a PV volume of 1.0), then remains approximately constant (dRm / dV ⁇ 0).
- the viscosity of the effluent reaches 100% of the viscosity of the solution injected after injection of a PV volume of less than 1.6 (24.8 cm 3 ).
- the core injection experiment was performed with a HP guar solution filtered through a 10 gm nylon filter as described above.
- the reduction of the mobility Rrrii increases until reaching approximately 6.5, then one observes a linear increase (dRm / dV ⁇ 0.45) around the injected volume PV of 10 corresponding to the injection of 133 cm 3 (fig.7).
- the concentration of the effluent stabilizes around a close value 97%, by reference to the stock solution.
- the core injection experiment is carried out with an HP-SVS guar solution after a first filtration using 12-15 ⁇ Durieux filters, then a second ultrafiltration using a 20 000 MWCO membrane, as described herein. -above.
- the reduction of the mobility Huey] increases to about 1, 58 (after injection into the pores of a PV volume of 1, 2), the viscosity of the effluent reaching 100% of the viscosity of the solution injected after injection of a PV volume of about 2 (26.6 cm 3 ) .
- the reduction in mobility increases to about 1.78 (after injection into pores with a PV volume of 1.2) and then remains approximately constant (dRm / dV ⁇ 0.0015).
- the viscosity of the effluent reaches 100% of the viscosity of the injected solution after injection of a PV volume of less than 2 (26.6 cm 3 ).
- the reduction in mobility increases until it reaches approximately 3 (after injection of a volume PV ⁇ 2), then it remains approximately constant (dRm / dV ⁇ 0) during the injection (PV 13,1).
- the viscosity of the effluent reaches 100% of the viscosity of the solution injected after injection of a PV volume of less than 2,
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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)
- Polysaccharides And Polysaccharide Derivatives (AREA)
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
Abstract
Description
Claims
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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US25834209P | 2009-11-05 | 2009-11-05 | |
PCT/FR2010/000729 WO2011055038A1 (fr) | 2009-11-05 | 2010-11-03 | Fluide d'injection et procede de recuperation assistee de petrole |
Publications (1)
Publication Number | Publication Date |
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EP2496659A1 true EP2496659A1 (fr) | 2012-09-12 |
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EP10787501A Withdrawn EP2496659A1 (fr) | 2009-11-05 | 2010-11-03 | Fluide d'injection et procede de recuperation assistee de petrole |
Country Status (4)
Country | Link |
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US (1) | US8613318B2 (fr) |
EP (1) | EP2496659A1 (fr) |
CA (1) | CA2779341C (fr) |
WO (1) | WO2011055038A1 (fr) |
Families Citing this family (9)
Publication number | Priority date | Publication date | Assignee | Title |
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CN102492048A (zh) * | 2011-11-29 | 2012-06-13 | 中国石油化学昆山公司 | 压裂液增稠剂及其含所述增稠剂的压裂液 |
GB201214313D0 (en) * | 2012-08-10 | 2012-09-26 | Oilflow Solutions Holdings Ltd | recovery of oil |
CN103113486B (zh) * | 2013-02-18 | 2015-08-05 | 中国石油天然气股份有限公司 | 磺酸改性羧甲基羟丙基瓜尔胶及其制备方法和应用 |
US9540667B2 (en) * | 2013-03-15 | 2017-01-10 | Halliburton Energy Services, Inc. | Methods of biosynthesizing bacterial extracellular galactomannan polysaccharides and subunits thereof for use in subterranean formation operations |
WO2015108812A1 (fr) * | 2014-01-14 | 2015-07-23 | Shell Oil Company | Composition et procédé destinés à la récupération de pétrole à partir d'une formation pétrolifère |
WO2016126761A1 (fr) * | 2015-02-03 | 2016-08-11 | Schlumberger Technology Corporation | Calcul de coefficient de viscosité de cisaillement de polymère à plusieurs phases en déroulement des opérations d'étude de simulation par injection de polymère dans une carotte |
WO2017182720A1 (fr) | 2016-04-20 | 2017-10-26 | Total Sa | Méthode de dosage d'additifs utilisés pour la récupération assistée du pétrole et du gaz de schiste |
CN107522791B (zh) * | 2016-06-20 | 2020-10-23 | 中国石油化工股份有限公司 | 一种含磺酸基的植物胶及其制备方法及应用 |
CN112145139B (zh) * | 2020-10-26 | 2022-02-01 | 西南石油大学 | 一种原油黏度合理映射聚合物驱使用浓度的方法 |
Family Cites Families (13)
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US3046272A (en) * | 1958-11-24 | 1962-07-24 | Scholten Chemische Fab | Polysaccharide-sultone reaction products |
GB1135693A (en) * | 1966-03-10 | 1968-12-04 | Scholten Chemische Fab | Polysaccharide derivatives |
US4524003A (en) * | 1983-04-08 | 1985-06-18 | Halliburton Company | Method of viscosifying aqueous fluids and process for recovery of hydrocarbons from subterranean formations |
US5378830A (en) | 1993-09-01 | 1995-01-03 | Rhone-Poulenc Specialty Chemicals Co. | Amphoteric polysaccharide compositions |
US20060142165A1 (en) * | 2003-09-24 | 2006-06-29 | Halliburton Energy Services, Inc. | Methods and compositions for treating subterranean formations using sulfonated gelling agent polymers |
JP4729043B2 (ja) * | 2004-10-08 | 2011-07-20 | アフィテック エーエス | 抗体ライブラリーをスクリーニングする方法 |
US20060151172A1 (en) | 2005-01-11 | 2006-07-13 | Halliburton Energy Services, Inc. | Methods of making and using sulfonated carboxylated polysaccharide gelling agents |
US7727945B2 (en) | 2005-07-15 | 2010-06-01 | Akzo Nobel N.V. | Modified polysaccharides |
WO2007058599A1 (fr) | 2005-11-21 | 2007-05-24 | Ge Healthcare Bio-Sciences Ab | Fabrication de matrice de chromatographie |
NO20073834L (no) | 2006-07-21 | 2008-01-22 | Akzo Nobel Chemicals Int Bv | Sulfonerte podede kopolymerer |
US20080021167A1 (en) | 2006-07-21 | 2008-01-24 | National Starch And Chemical Investment Holding Co | Sulfonated graft copolymers |
US8586508B2 (en) * | 2007-05-30 | 2013-11-19 | Halliburton Energy Services, Inc. | Polysaccharide based cement additives |
WO2010036729A2 (fr) * | 2008-09-26 | 2010-04-01 | Bp Corporation North America Inc. | Compositions de traitement de puits de forage |
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2010
- 2010-11-03 EP EP10787501A patent/EP2496659A1/fr not_active Withdrawn
- 2010-11-03 CA CA2779341A patent/CA2779341C/fr not_active Expired - Fee Related
- 2010-11-03 WO PCT/FR2010/000729 patent/WO2011055038A1/fr active Application Filing
- 2010-11-04 US US12/939,310 patent/US8613318B2/en not_active Expired - Fee Related
Non-Patent Citations (2)
Title |
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See also references of WO2011055038A1 * |
Also Published As
Publication number | Publication date |
---|---|
WO2011055038A1 (fr) | 2011-05-12 |
CA2779341A1 (fr) | 2011-05-12 |
US8613318B2 (en) | 2013-12-24 |
CA2779341C (fr) | 2018-01-02 |
US20110100631A1 (en) | 2011-05-05 |
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