WO2008084227A1 - Fluides de traitement de lavage aux tensio-actifs et procédés associés - Google Patents

Fluides de traitement de lavage aux tensio-actifs et procédés associés Download PDF

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Publication number
WO2008084227A1
WO2008084227A1 PCT/GB2008/000068 GB2008000068W WO2008084227A1 WO 2008084227 A1 WO2008084227 A1 WO 2008084227A1 GB 2008000068 W GB2008000068 W GB 2008000068W WO 2008084227 A1 WO2008084227 A1 WO 2008084227A1
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WIPO (PCT)
Prior art keywords
acid
poly
esters
surfactant
derivatives
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Application number
PCT/GB2008/000068
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English (en)
Inventor
David L. Carbajal
Kenneth W. Oyler
William W. Shumway
Ian D. Robb
Eric A. Davidson
Original Assignee
Halliburton Energy Services, Inc.
Curtis, Philip, Anthony
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Filing date
Publication date
Priority claimed from US11/622,907 external-priority patent/US20080169103A1/en
Priority claimed from US11/622,898 external-priority patent/US8220548B2/en
Application filed by Halliburton Energy Services, Inc., Curtis, Philip, Anthony filed Critical Halliburton Energy Services, Inc.
Publication of WO2008084227A1 publication Critical patent/WO2008084227A1/fr

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    • 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
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • 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
    • C09K8/72—Eroding chemicals, e.g. acids

Definitions

  • the present invention relates to clean up operations in subterranean well bores, and more particularly, to surfactant wash treatment fluids that may be used in clean-up operations to render the well bore water-wet and/or remove oil wet solids in well bores that may be present as a result of using oil-based drilling or drill-in fluids or other fluids including aqueous-based fluids that may comprise an oily component.
  • the compositions and methods of the present invention are applicable to both hydrocarbon- producing wells as well as to injection wells.
  • Oil-based fluids e.g., drilling or drill-in fluids are often used in subterranean applications.
  • the choice of oil-based or water based types of fluids is often driven by performance characteristics of each fluid, the type of well to be drilled, cost considerations and the characteristics of the oil or gas field in which the well is to be drilled as well as environmental concerns.
  • the primary potential benefits of selecting an oil-based fluid are thought to include: superior hole stability, especially in shale formations; well bores with less wash out potential, providing wells that are more in gauge with the bit; formation of a tliinner filter cake than a filter cake achieved with a water-based fluid; excellent lubrication of the drill string and down hole tools; penetration of salt beds without sloughing or enlargement of the hole; greater rate of bit penetration; better tolerance to fluid contamination as well as other benefits that should be known to those skilled in the art.
  • a water based fluid may be used that contains a substantial amount of an oily component(s) in order to achieve some of these same performance characteristics as oil based fluids.
  • Oil-based fluids usually contain some water, either formed in the formulation of the drilling fluid itself, or residual water in the hole, or intentionally added water to affect the properties of the drilling fluid or mud. Those that contain intentionally added water are often in an emulsion form, and are often referred to as invert emulsions.
  • an emulsifier is usually included to stabilize the emulsion.
  • Typical examples of such emulsifiers include polyvalent metal soaps, fatty acids, fatty acid soaps, fatty amides, and other similar suitable compounds.
  • An especially beneficial property of oil-based fluids is their excellent lubrication qualities. These lubrication properties permit the drilling of wells having a significant vertical deviation, as is typical in off-shore or deep water drilling operations or when a horizontal well is desired. In such highly deviated holes, torque and drag on the drill string can be a significant problem because the drill pipe lies against the low side of the hole, and the risk of pipe sticking is high when water based fluids are used. In contrast, oil-based fluids provide a thin, slick filter cake which helps to prevent pipe sticking, and thus the use of the oil-based fluid may be beneficial.
  • oil-based drilling fluids and fluids can have high initial and operational costs. These costs can be significant depending on the depth of the hole to be drilled. However, the higher costs may be justified by the improved performance of the oil based drilling fluid, which in addition to the previously mention benefits also may prevent the caving in or hole enlargement that can greatly increase drilling time. Use of oil based fluids can often result in lower overall well construction costs because of simplified drilling and reduced subsequent completion costs.
  • the filter cake usually should be cleaned up for optimum production to occur.
  • the filter cake preferably needs to be removed and the formation solids should be left water-wet.
  • the oil-wet filter cake should be treated in some manner that results in converting the oil-wet solids contained in the filter cake to water- wet solids, which can then be treated and removed from the well bore.
  • the resultant well bore should be rendered water-wet. Production can then occur. Production after a clean up is often thought to be superior to production without filter cake clean up.
  • One method that has been developed to clean up oil-wet solids that remain in the well bore as a result of using an oil-based fluid is a two-step process involving a mutual solvent treatment followed by an acid treatment.
  • a mutual solvent to clean up oil-wet solids that result from using an oil based fluid is often thought to be necessary prior to acid treatment to avoid the formation of an undesirable residue that is extremely viscous and that can cause more damage from emulsion blockage than not doing the clean up in the first place.
  • a solvent that is soluble in oil and water usually is used to wash away the oil from the solids so that the solids can then be dissolved or broken down by an acid treatment.
  • suitable mutual solvents may include isopropanol or EGMBE. Washing the solids with the mutual solvent is thought to enable the acid to interact with the solids to degrade them.
  • the present invention relates to clean up operations in subterranean well bores, and more particularly, to surfactant wash treatment fluids that may be used in clean-up operations to render the well bore water-wet and/or remove oil wet solids in well bores that may be present as a result of using oil-based drilling or drill-in fluids or other fluids including aqueous-based fluids that may comprise an oily component.
  • the present invention provides a method comprising: providing an oil-wet well bore surface; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; contacting the oil-wet well bore surface with the surfactant wash treatment fluid; allowing the oil-wet well bore surface to become water-wet; and producing fluids from the formation.
  • the present invention provides a method comprising: providing an oil-wet solid located in a subterranean formation; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid- generating component, and an aqueous fluid; contacting the oil-wet solid with the surfactant wash treatment fluid; and allowing the oil- wet solid to become water- wet.
  • the present invention provides a method comprising: providing an oil-wet well bore surface; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; and contacting the well bore surface with the surfactant wash treatment fluid.
  • the present invention provides a method comprising: drilling a well bore using an oil-based fluid or an aqueous fluid comprising an oily component; creating an oil-wet well bore surface; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; contacting the oil-wet well bore surface with the surfactant wash treatment fluid; and allowing the oil-wet well bore surface to become water wet.
  • the present invention provides a method comprising: drilling a well bore in a subterranean formation using a fluid that is oil-based or an aqueous-based fluid that comprises an oily component wherein oil-wet solids are deposited on a surface within the well bore; providing a surfactant wash treatment fluid that comprises an aqueous fluid, an acid-compatible surfactant; and an acid and/or an acid- generating component; introducing the surfactant wash treatment fluid into the subterranean formation; and allowing production to occur.
  • the present invention provides a surfactant wash treatment fluid for use in a subterranean formation comprising an aqueous fluid, an acid- compatible surfactant, an acid and/or an acid-generating component.
  • Figure 1 illustrates data as described in the examples herein.
  • Figure 2 illustrates data as described in the examples herein.
  • Figure 3 illustrates data as described in the examples herein.
  • Figure 4 illustrates data as described in the examples herein.
  • the present invention relates to clean up operations in subterranean well bores, and more particularly, to surfactant wash treatment fluids that may be used in clean-up operations to render the well bore water-wet and/or remove oil wet solids in well bores that may be present as a result of using oil-based drilling or drill-in fluids or other fluids including aqueous-based fluids that may comprise an oily component.
  • compositions and methods of the present invention are applicable to both hydrocarbon-producing wells as well as to injection wells.
  • compositions and methods of the present invention are useful in the clean up of oil-wet solids within a well bore to convert them to water-wet solids and then degrade those solids.
  • One of the many other benefits of the compositions and methods of the present invention is that they are believed to be non-damaging to a subterranean formation.
  • the compositions and methods of the present invention allow operators to use conventional oil-based drill-in fluids and achieve proper filter cake removal.
  • Perhaps one of the more important potential benefits of the compositions and methods of the present invention is that they remove the oil wet filtercake and leave the formation substantially water- wet in one treatment step.
  • the compositions and methods of the present invention may involve either live acids or acid generating components for enhanced flexibility in completion operations. Other potential advantages and benefits may be recognized by those skilled in the art upon reviewing this disclosure.
  • the methods of the present invention generally involve first drilling a well bore in a subterranean formation using a fluid that is oil-based ⁇ e.g., an oil-based drilling or a drill-in fluid, an invert emulsion, a fluid comprising substantially no aqueous components, and the like) or an aqueous-based fluid that comprises an oily component(s), and that as a result of the drilling process, oil-wet solids are deposited on the sides or other surfaces within the well bore.
  • a fluid that is oil-based e.g., an oil-based drilling or a drill-in fluid, an invert emulsion, a fluid comprising substantially no aqueous components, and the like
  • an aqueous-based fluid that comprises an oily component(s
  • oil-wet solids may be components of the filter cake, a formation face, a fracture face, a perforation, or on a screen (e.g., a gravel pack screen) or another piece of equipment located in the well bore or subterranean formation.
  • the drilling portion of the process may be performed by the same or a different party than the party that performs the clean-up operation involving the methods and compositions of the present invention; either is contemplated within the scope of this invention.
  • the oil or oily component used in a fluid may include olefins, kerosene, diesel oil, fuel oil, synthetic oils, linear or branched paraffins, olefins, esters, acetals, mixtures of crude oil, and combinations and derivatives thereof. Others may be suitable as well as recognized by one skilled in the art.
  • an embodiment of a surfactant wash treatment fluid of the present invention may be used that comprises an aqueous fluid, an acid, and an acid-compatible surfactant.
  • the surfactant wash treatment fluid may be introduced into the subterranean formation by any appropriate technique or method used in the art.
  • the surfactant wash treatment fluid the oil-wet solids in the subterranean formation should become water-wet, and then should degrade. Production can then take place, if desired or appropriate, as for example in a hydrocarbon-producing well.
  • the surfactant wash treatment fluids of the present invention may comprise an aqueous fluid, a surfactant, and optionally an acid or an acid-generating component.
  • the surfactant wash treatment fluids may comprise additional components including corrosion inhibitors, corrosion inhibitor intensifiers, bactericides, antioxidants, enzymes, salts, weighting agents, viscosifiers, and any derivative or combination thereof.
  • additional additives examples include, but are not limited to, pH-adjusting agents, pH-buffers, oxidizing agents, lost circulation materials, scale inhibitors, surfactants, clay stabilizers, paraffin inhibitors, asphaltene inhibitors, penetrating agents, clay control additives, iron control additives, chelators, reducers, oxygen scavengers, sulfide scavengers, emulsifiers, foamers, gases, gelling agents, viscosifiers, derivatives thereof and combinations thereof, and the like.
  • pH-adjusting agents pH-buffers
  • oxidizing agents lost circulation materials
  • scale inhibitors surfactants
  • clay stabilizers paraffin inhibitors
  • asphaltene inhibitors asphaltene inhibitors
  • penetrating agents clay control additives
  • iron control additives iron control additives
  • chelators reducers
  • oxygen scavengers sulfide scavengers
  • emulsifiers foamers, gases, gelling agents, viscosifiers
  • Suitable aqueous fluids that may be used in the surfactant wash treatment fluids of the present invention include any aqueous fluid suitable for use in subterranean applications.
  • brines may be preferred.
  • Suitable brines include, but are not limited to: NaCl, NaBr, CaCl 2 , CaBr 2 , ZrBr 2 , sodium formate, potassium formate, caesium formate, and combinations and derivatives of these brines. NaBr may be preferredin some instances.
  • Other brines suitable for use in subterranean applications also may be suitable. The specific brine used may be dictated by the desired density of the resulting surfactant wash treatment fluid. Denser brines may be useful in some instances.
  • the aqueous fluid should comprise the balance of the surfactant wash treatment fluid after considering the amount of the acid (or acid-generating component) and/or surfactant present.
  • an acid and/or an acid-generating component may be included in a separate fluid that follows a wash fluid that comprises an aqueous fluid and an acid-compatible surfactant.
  • Suitable acids that may be used in the surfactant wash treatment fluids of the present invention include any acid suitable for use in subterranean applications. Examples include, but are not limited to, inorganic acids such as hydrochloric acid, hydrofluoric acid, hydrobromic acid, sulfuric acid, phosphoric acid, and nitric acid, and organic acids such as acetic acid, formic acid, glycolic acid, lactic acid, amino acid, dibasic acid, aromatic acid, and aliphatic acids. Combinations and derivatives of these are also suitable. Other acids that are suitable for use in subterranean applications may also be suitable. In some embodiments of the present invention, the acid is hydrochloric acid.
  • the amount of acid to include in a surfactant wash treatment fluid of the present invention may be determined by the expected volume of solids (e.g., bridging agents or scale) to be removed. In some instances, the amount of acid to include may vary from about 0.1% to about 40% of the surfactant wash treatment fluid. Considerations that may be taken into account when deciding how much acid to use include: expected thickness of filtercake and calcium carbonate concentration and the volume of the contiguous acid containing breaker. Thus, the diameter of the bore hole, the temperature, and the required brine density should be considered. Other considerations are known to those skilled in the art. . Preferably, if an acid is used as opposed to an acid-generating component as described below, the acid remains live until it reacts with the acid-soluble solids in the well bore.
  • acid-generating components i.e., those that will generate an acid at a later time
  • acid-generating components may be useful in situations where one treatment may be performed to cover an entire section of a well bore. The well bore may be shut-in, and then cleaned up. The time at which the acid-generating component generates an acid may be controlled by the choice of the acid-generating component as well as the conditions present in the well bore.
  • Suitable acid-generating components may include: poly(ortho esters), orthoesters (which may also be known as “poly ortho ethers” or “ortho ethers”); esters of organic acids such as esters of formic acid, esters of acetic acid, esters of lactic acid, and esters of oxalic acid.
  • Other suitable acid generating components may include other esters; aliphatic polyesters; poly(lactides); poly(glycolides); poly( ⁇ -caprolactones); poly(hydroxybutyrates); poly (anhydrides); poly( amino acids); poly lactic acid; or copolymers thereof. Derivatives and combinations also may be suitable.
  • Suitable acid generating components may include: formate esters including, but are not limited to, ethylene glycol monoformate, ethylene glycol diformate, diethylene glycol diformate, glyceryl monoformate, glyceryl diformate, glyceryl triformate, triethylene glycol diformate and formate esters of pentaerythritol. Ethyl and methyl lactate may also be suitable.
  • Other suitable materials may be disclosed in U.S. Patent Nos. 6,877,563 and 7,021,383, the disclosures of which are incorporated by reference. Most of these are commercially available in liquid form, and may be used in that form. However, solid forms of these acid-generating components may be used beneficially in the methods of the present invention.
  • the acid-generating components may be reacted with small amounts of reactive materials such as mineral acids, organic acids, acidic anhydrides, p-toluenesulfonic acid, etc. to lower the pH to accelerate the hydrolysis of the acid-generating component.
  • the hydrolysis rate may be slowed by the addition of a small amount of a strong base such as NaOH 3 Na 2 CO 3 , NaHCO 3 and Mg(OH) 2 .
  • the acid-generating component also may generate alcohols down hole that may be beneficial to the operation.
  • These alcohols can act as surface tension reducers, e.g., to keep any nonemulsifiers and surface tension reducers in solution so that they are not absorbed into the formation.
  • These alcohols may be used to clean out condensate blockages that may prevent flow due to accumulation of condensate in the formation or due to accumulation of water or water emulsions in the pore volumes of the formation.
  • These alcohols may also act as hydrate inhibitors. Delayed generation of these alcohols can be beneficial in other ways as well. For instance, the production of these alcohols down hole gives the distinct advantage of being able to provide the alcohols down hole without having to pump them.
  • the delayed generation may be useful.
  • these generated alcohols may be preferred over standard alcohols because some standard. alcohols contain chemical inhibitors that may interact with the chemistry within the well bore in such a way as to be problematic. Moreover, shipping and storing standard alcohols may be problematic. The particular alcohol given off depends on the acid-generating component being used. For instance, trimethylorthoformate gives off three molecules of methanol for each molecule of formic acid; the methanol may be useful for hydrate inhibition. Others might also be suitable.
  • Guidelines for choosing a suitable acid-generating component may include the time at which the acid is desired relative to the placement of the acid-generating component in the well bore, the environmental conditions presented, the conditions within the well bore, the temperature of the well bore section in which the acid-generating component is being placed, the composition of the formation water, etc. Other considerations may be evident to those skilled in the art.
  • Suitable acid-compatible surfactants are preferably non-damaging to the subterranean formation.
  • the acid-compatible surfactant may be included in an amount of up to about 100% of a surfactant wash treatment fluid of the present invention, if desired. Suitable amounts for most cases may be from about 0.1% to about 20%, depending on the circumstances. However, using 5% or less is generally preferred and suitable under most circumstances, hi certain embodiments, the acid-compatible surfactant may be included in a surfactant wash treatment fluid of the present invention in amount of from about 0.5 to about 4% of the surfactant wash treatment fluid. Considerations that may be taken into account when deciding how much to use include the amount of solids that will need to be degraded, and the diameter of the well bore. Other considerations may be evident to one skilled in the art with the benefit of this disclosure.
  • suitable acid-compatible surfactants include fatty betaines that are dispersible in oil.
  • suitable fatty betaines preferably carboxy betaines may be chosen because they are more acid sensitive.
  • betaines include lauramidopropyl betaine.
  • suitable surfactants include ethylene oxide propylene oxide ("EO/PO") block copolymers.
  • EO/PO ethylene oxide propylene oxide
  • suitable surfactants include fatty ⁇ amines and fatty polyamines as well as hydrophilically modified amines and polyamines with HLB values of from about 3 to about 10.
  • Suitable hydrophilically modified polyamines can include, but are not limited to, ethoxylated and propoxylated derivatives of these.
  • ethoxylated tallow triamine examples include ethoxylated tallow triamine.
  • An ethoxylated tallow triamine is currently available as "GS 22- 89B” from Special Products and ethoxylated oleyl amine currently available from AKZO Nobel as "Ethomeen S/12.”
  • suitable fatty polyamines include, but are not limited to, soya ethylenediamine, and tallow diethylene triamine.
  • Suitable fatty amine examples include, but are not limited to, soya amine.
  • Hydrophilically modified fatty amine examples include ethoxylated soya amines. In some instances, lauramidopropyl betaine may be preferred.
  • Lauramidopropyl betaine is currently available commercially as “AMPHOSOL® LB” from Stepan Company. In other instances, an EO/PO block copolymer may be preferred.
  • a block copolymer of ethylene oxide and propylene oxide is currently available commercially as “Synperonic® PE/L64" from Uniqema.
  • the present invention provides a method comprising: providing an oil-wet well bore surface; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; contacting the oil-wet well bore surface with the surfactant wash treatment fluid; allowing the oil-wet well bore surface to become water-wet; and producing fluids from the formation.
  • the present invention provides a method comprising: providing an oil-wet solid located in a subterranean formation; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; contacting the oil-wet solid with the surfactant wash treatment fluid; and allowing the oil-wet solid to become water- wet.
  • the present invention provides a method comprising: providing an oil-wet well bore surface; providing a. surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; and contacting the well bore surface with the surfactant wash treatment fluid. .... J . .
  • the present invention provides a method comprising: drilling a well bore using an oil-based fluid or an aqueous fluid comprising an oily component; creating an oil-wet well bore surface; providing a surfactant wash treatment fluid that comprises an acid-compatible surfactant, an acid and/or an acid-generating component, and an aqueous fluid; contacting the oil- wet well bore, surf ace with the surfactant wash treatment fluid; and allowing the oil-wet well bore surface to become water wet.
  • the present invention provides a method comprising: drilling a well bore in a subterranean formation using a fluid that is oil- based or an aqueous-based fluid that comprises an oily component wherein oil-wet solids are deposited on a surface within the well bore; providing a surfactant wash treatment fluid that comprises an aqueous fluid, and an acid-compatible surfactant, and an acid and/or an acid- generating component; introducing the surfactant wash treatment fluid into the subterranean formation; and allowing production to occur.
  • the present invention provides a surfactant wash treatment fluid for use in a subterranean formation comprising an aqueous fluid, an acid- compatible surfactant, an acid and/or an acid-generating component.
  • Example 1 Screening of Surfactants using 15% wt. HCl / NaBr with a
  • a 10 bbl equivalent batch of the base 9.5 ppg, XP-07 based, 65/35 oil- to-water ratio, and 365,478 ppm Water Phase Salinity, water-in-oil fluid was mixed using a Silverson fitted with a square head emulsion screen. This fluid was used in building the oily filter cakes that were evaluated in the following examples.
  • the formulation components, rheological properties, and filtration properties can be seen in Table 1.
  • "XP-07” is paraffin base oil available from Halliburton Energy Services in Duncan, Oklahoma or Houston, Texas.
  • LE SUPERMUL is an emulsifier available from Halliburton Energy Services in Duncan, Oklahoma or Houston, Texas.
  • GELTONE II is an organophilic clay available from Halliburton Energy Services in Duncan, Oklahoma or Houston, Texas.
  • RHEMOD L is a liquid rheology modifier available from Halliburton Energy Services in Duncan, Oklahoma or Houston, Texas.
  • BARACARB 5 “BARACARB 25,” and “BARACARB 50” are all bridging agents available from Energy Services in Duncan, Oklahoma or Houston, Texas.
  • the HCl live acid testing protocol used to evaluate the surfactants was as follows. First, a 9.5 ppg, XP-07 based, 65/35 oil-to-water ratio, and 365,478 ppm Water Phase Salinity water-in-oil fluid was formulated and mixed. Table 1 illustrates the components and properties of the fluid.
  • a surfactant wash treatment fluid 100 ml of a surfactant wash treatment fluid were made by combining 58.7 grams of tap water and 9.1 grams of dry NaBr salt. The mixture was stirred with spatula until the salt dissolved in the water. At that point, 46.3 grams of concentrated HCl (37% by wt.) were added to the mixture, and the mixture was then stirred with a spatula to obtain homogeneity.
  • the acid solution was mixed thoroughly and then poured into the double ended filtration cell and onto the remaining filter cake on the aloxite ceramic disc from above.
  • the cell was then reassembled and placed into a heating jacket pre-heated to 180°F. 100 psi was applied to the top regulator (no bottom regulator was required). Once the cell reached 180 0 F, a timer was set for 4 hours. Every hour, the bottom valve was opened to see if acid breaker filtrate was present, which was thought to indicate that some filter cake deterioration had occurred.
  • the acid breaker filtrate was collected in a 500 ml beaker.
  • the double ended filtration cell was closed and removed from the heating jacket. The cell was then cooled in a water bath.
  • the double ended filtration cell was opened and any remaining surfactant wash treatment fluid was removed.
  • the cell was filled with "Soltrol 170," which is paraffin oil available from Chevron.
  • the end cap was used in a modified permeability test setup.
  • the cell was connected to an Alltech model 526 HPLC constant rate/variable pressure pump using a reservoir of Soltrol 170 as the mobile phase.
  • the pump output was then set to 10 ml/min.
  • the valve was then opened, and pumping was commenced in the production direction.
  • the pressure required to flow Soltrol 170 across the filter cake over time was the data that was collected. Data was collected for a total of 40 minutes per sample.
  • the ETHOMEEN SV/12 product appeared to show lower dispersibility than the GS 22-89 B and the AMPHOSOL LB in the surfactant wash treatment fluid.
  • the ETHOMEEN SV/12 did eventually disperse fully after approximately 5 minutes of stirring with a spatula.
  • Example 2 Screening of Surfactants using BDF-325 / NaBr / Gravel
  • surfactants that were used in the first example described above were used in this example. These surfactants were AMPHOSOL LB, GS 22-89 B, ETHOMEEN SV/12, and Synperonic PE/L64. "BDF-325,” which is a delayed acid breaker available from Halliburton Energy Services in Duncan, Oklahoma or Houston, Texas, was used in a 20% v/v concentration with one of these surfactants in a surfactant wash treatment fluid in a gravel pack simulation. NaBr salt was again utilized to help provide the adequate density for the surfactant wash treatment fluid, and 20/40 sand was utilized for the gravel pack application.
  • the cell was then cooled and any excess fluid was removed.
  • the filter cake was then rinsed with approximately 50 to 75 ml of XP-07 base oil to remove excess loosely consolidated filter cake solids.
  • the cell was removed and cooled in a water bath. After the cooling period, the cell was connected to an Alltech model 526 HPLC constant rate/variable pressure pump using a reservoir of Soltrol 170 as the mobile phase. The pump was set to output to 10 ml/min of Soltrol 170. The valve was opened, and started pumping in the production direction. Pressure data was collected for a total of 40 minutes per sample.
  • every range of values (of the form, "from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b") disclosed herein is to be understood as referring to the power set (the set of all subsets) of the respective range of values, and set forth every range encompassed within the broader range of values.
  • the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee.

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Abstract

Parmi de nombreux procédés et compositions, l'invention concerne un procédé qui, dans un mode de réalisation, consiste à: disposer d'une surface de puits de forage mouillée à l'huile; obtenir un fluide de traitement de lavage aux tensio-actifs comprenant un tensio-actif compatible avec les acides, un acide et/ou un composant générateur d'acide, et un fluide aqueux; mettre en contact la surface de puits mouillée à l'huile avec le fluide de traitement de lavage aux tensio-actifs; laisser la surface de puits de forage mouillée à l'huile se mouiller à l'eau; et produire des fluides à partir de la formation. Dans un autre mode de réalisation, l'invention porte sur un fluide de traitement de lavage utilisé dans une formation souterraine, qui comprend un fluide aqueux, un tensio-actif compatible avec les acides, un acide et/ou un composant générateur d'acide.
PCT/GB2008/000068 2007-01-12 2008-01-09 Fluides de traitement de lavage aux tensio-actifs et procédés associés WO2008084227A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US11/622,907 2007-01-12
US11/622,898 2007-01-12
US11/622,907 US20080169103A1 (en) 2007-01-12 2007-01-12 Surfactant Wash Treatment Fluids and Associated Methods
US11/622,898 US8220548B2 (en) 2007-01-12 2007-01-12 Surfactant wash treatment fluids and associated methods

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KR20150064660A (ko) * 2013-12-03 2015-06-11 주식회사 엘지화학 에스터 화합물의 제조방법 및 이에 의하여 제조된 에스터 화합물
KR20150064498A (ko) * 2013-12-03 2015-06-11 주식회사 엘지화학 아세톤을 이용하여 수율을 개선한 에스터 화합물의 제조방법
CN107267131A (zh) * 2016-04-08 2017-10-20 中国石油化工股份有限公司 一种油基钻井液固井用冲洗液及其资源再利用方法及应用

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US8921295B2 (en) 2010-07-23 2014-12-30 American Sterilizer Company Biodegradable concentrated neutral detergent composition
US20150152036A1 (en) * 2013-12-03 2015-06-04 Lg Chem, Ltd. Method of preparing ester compound and ester compound prepared thereby
KR20150064660A (ko) * 2013-12-03 2015-06-11 주식회사 엘지화학 에스터 화합물의 제조방법 및 이에 의하여 제조된 에스터 화합물
KR20150064498A (ko) * 2013-12-03 2015-06-11 주식회사 엘지화학 아세톤을 이용하여 수율을 개선한 에스터 화합물의 제조방법
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KR101709670B1 (ko) 2013-12-03 2017-02-23 주식회사 엘지화학 아세톤을 이용하여 수율을 개선한 에스터 화합물의 제조방법
CN107267131A (zh) * 2016-04-08 2017-10-20 中国石油化工股份有限公司 一种油基钻井液固井用冲洗液及其资源再利用方法及应用

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