WO2013089896A2 - Fluides pour des opérations de récupération d'hydrocarbures et leurs procédés d'utilisation - Google Patents

Fluides pour des opérations de récupération d'hydrocarbures et leurs procédés d'utilisation Download PDF

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Publication number
WO2013089896A2
WO2013089896A2 PCT/US2012/058797 US2012058797W WO2013089896A2 WO 2013089896 A2 WO2013089896 A2 WO 2013089896A2 US 2012058797 W US2012058797 W US 2012058797W WO 2013089896 A2 WO2013089896 A2 WO 2013089896A2
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fluid
operations
wellbore
filter cake
organo
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WO2013089896A3 (fr
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Sabine C. Zeilinger
Ramesh Varadaraj
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ExxonMobil Upstream Research Co
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ExxonMobil Upstream Research Co
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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
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/501—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls using spacer compositions
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • C09K8/524—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
    • 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
    • C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates

Definitions

  • the present disclosure relates generally to hydrocarbon recovery operations, including drilling operations, completion operations, production operations, and injection operations. More particularly, the present disclosure relates to fluids and methods for addressing various problems presented by filter cakes during hydrocarbon recovery operations.
  • hydrocarbons refers to an organic compound that includes primarily, if not exclusively, the elements hydrogen and carbon.
  • hydrocarbon-containing materials include any form of natural gas, oil, coal, and bitumen that can be used as a fuel or upgraded into a fuel.
  • Hydrocarbons are commonly found in subsurface formations.
  • formation refers to a subsurface region, regardless of size, comprising an aggregation of subsurface sedimentary, metamorphic, and/or igneous matter, whether consolidated or unconsolidated, and other subsurface matter, whether in a solid, semi-solid, liquid and/or gaseous state.
  • a formation can refer to a single set of related geologic strata of a specific rock type, or to a whole set of geologic strata of different rock types that contribute to or are encountered in, for example, without limitation, (i) the creation, generation and/or entrapment of hydrocarbons or minerals and (ii) the execution of processes used to extract hydrocarbons or minerals from the subsurface.
  • the wells may be completed, such as by positioning one or more pieces of downhole equipment in the borehole (i.e., the space evacuated by the drilling operation within the wellbore, which refers to the formation face).
  • formation fluids may be produced into the borehole and to the surface.
  • fluids may be injected into the formation from the borehole for a variety of reasons, such as to treat the near-well region of the formation, to drive formation fluids towards another well, to sequester fluids or gases, etc.
  • hydrocarbon production refers to any activity associated with extracting hydrocarbons from a well or other opening. Hydrocarbon production normally refers to any activity conducted in or on the well after the well is completed. Accordingly, hydrocarbon production includes not only primary hydrocarbon extraction, but also includes secondary and tertiary production techniques, such as injection of gas or liquid for increasing drive pressure; mobilizing the hydrocarbon or treating by, for example, chemical or hydraulic fracturing of the wellbore to promote increased flow; well servicing; well logging; and other well and wellbore treatments.
  • hydrocarbon recovery operations will be used to refer to them collectively and individually. For example, the term hydrocarbon recovery operations refers to each and all of drilling operations, completion operations, hydrocarbon production operations, and injection operations (regardless of the fluid being pumped into the borehole or the purpose for which it is being pumped).
  • Filter cake as used herein may refer to the residue deposited on a medium, which is frequently a permeable medium, when a slurry, such as a drilling fluid, is forced against the medium under a pressure.
  • Filter cake properties such as cake thickness, toughness, slickness, and permeability, are important because the cake that forms on permeable regions of the wellbore can be beneficial to an operation or may be detrimental to an operation.
  • the problems that a filter cake may present include reduced permeability during production and/or injection operations.
  • the reduced permeability of a filter cake may also limit the ability of an operator to treat common problems during drilling operations, such as stuck pipe and lost returns. While filter cakes can present numerous challenges or disadvantages, operators also know that there are various advantages provided by filter cakes, such as limiting the loss of drilling fluid to the formation, reducing risks of contaminating or damaging a reservoir during drilling, retaining formation fluids during drilling to prevent kicks, etc. Accordingly, there has been a long history of publications and inventions directed to targeted creation and destruction of filter cakes.
  • Exemplary teachings known in the art include the use of chelating agents to extract metallic weighting agents from filter cakes, the use of acidic treatment fluids to dissolve the filter cake elements, and/or the use of surfactants to clean the filter cake from the surface of the wellbore.
  • Exemplary publications of such teachings may be found in U.S. Patent Publication No. 2008/01 10621 , which is incorporated herein in its entirety for all purposes. While this and other documents are incorporated herein in their entirety, the definition or usage of a term in this specification will control if there is any conflict between the definition or usage of a term in this specification and the specification of another patent document incorporated herein by reference.
  • Other exemplary related publications may be found in U.S. Patent Publication Nos.
  • Filter cakes may be formed from aqueous and non-aqueous slurries.
  • the properties of the filter cakes and the available remediation methods may vary depending on the type of slurry used when the filter cake forms.
  • NAF non-aqueous fluid
  • filter cakes formed from a non-aqueous fluid (NAF) such as an oil-based or synthetic oil-based drilling mud
  • NAF filter cakes exhibit far less permeability than a filter cake formed from an aqueous fluid and are also more difficult to remediate.
  • NAF filter cakes may suggest using aqueous drilling fluids to avoid the NAF filter cake
  • some implementations require NAF drilling fluids for a variety of reasons, as is well known.
  • some implementations benefit from the decreased permeability during some stages of the drilling operation, but then need the NAF filter cake remediated after the drilling or as part of a lost returns treatment during the drilling operations.
  • the decreased permeability of a NAF filter cake, or filter cake formed from NAF slurries has been observed to complicate the remediation of the filter cake, often necessitating complex treatment fluids.
  • the NAF filter cake is only treatable by using a coordinated system of drilling muds and treating fluids.
  • Other proposed solutions have attempted to use chelating agents to remove metallic weighting agents from the filter cake. While these solutions provide some improvement or some level of remediation, the conventional approaches are costly and complex. Accordingly, the need exists for systems and/or methods for remediating NAF filter cake, whether for the purpose of continuing drilling operations, such as in the event of lost returns, or for the purpose of improving production and/or injection operations.
  • the present disclosure is directed to fluids for use in hydrocarbon recovery operations, to methods of using such fluids, and to methods for conducting such hydrocarbon recovery operations.
  • exemplary fluids may be referred to as operations fluid and may comprise water, an alkyl acid, and at least one organo-anionic surfactant.
  • the operations fluid may be adapted to perform as a treatment fluid for use during at least one of drilling operations, completion operations, production operations, injection operations, and/or other operations associated with the recovery of hydrocarbons from subsurface formations.
  • the operations fluid may be adapted to remediate a NAF filter cake.
  • the operations fluid may be adapted to remediate the filter cake by performing at least one of: 1 ) altering the wettability of the NAF filter cake from oil wetting to water wetting; and 2) extracting non-aqueous fluid associated with the NAF filter cake.
  • the organo-anionic surfactant of the operations fluid may have the general formula: ⁇ R-X ⁇ " + ⁇ Y ⁇ .
  • R may be selected from the group comprising linear and branched alkyl and aryl alkyl hydrocarbon chains;
  • X may be an acid selected from the group comprising sulfonic acids, carboxylic acids, phosphoric acids, and mixtures thereof; and
  • Y may be an organic amine selected from the group comprising monoethanol amine, diethanol amine, triethanol amine, ethylene diamine, propylene diamine, diethylene tri-amine, tri- ethylene tetra-amine, tetra ethylene pent-amine, dipropylene tri-amine, tripropylene tetra- amine, tetra propylene pentamine, and mixtures thereof.
  • the claimed subject matter may include a treatment system for operations on wells associated with hydrocarbon production, the treatment system comprising: preparing a treatment pill comprising; water, at least one organo-anionic surfactant, an alkyl acid, and a particulate material; and including a step of placing the treatment pill into a wellbore associated with hydrocarbon production.
  • Associated with hydrocarbon production is defined broadly to include any wellbore that serves a useful purpose affiliate with operations in a hydrocarbon producing field.
  • An exemplary method of utilizing the operations fluid may be in a method of remediating a NAF filter cake in a well.
  • Exemplary implementations include: 1 ) obtaining an operations fluid comprising an organo-anionic surfactant and an alkyl acid in water; 2) pumping a volume of the operations fluid into a well including a NAF filter cake, wherein the volume of operations fluid is pumped to contact the NAF filter cake.
  • Such methods may be applied with the NAF filter cake disposed in a variety of manners within the well.
  • the NAF filter cake may be disposed on at least one of a fracture face, a sand screen, gravel pack components, and a wellbore wall.
  • the remediation method may be applied during a drilling operation experiencing lost returns, wherein active drilling is paused while the remediation method is applied. Additionally or alternatively, the volume of the operations fluid may be applied during at least one of drilling operations, completion operations, production operations, and injection operations.
  • the fluids may be utilized in methods of drilling a well.
  • Exemplary methods may include: 1 ) drilling through a formation using a NAF-based drilling fluid, such as a hydrocarbon based or hydrocarbon containing drilling fluid, to form a wellbore until a fracture undesirably forms in the formation, causing loss of circulation of at least a portion of the circulating drilling fluid; 2) pumping an operations fluid into the wellbore and into the fracture, wherein the operations fluid comprises an organo-anionic surfactant and an alkyl acid, in water; 3) applying a fracture closure stress treatment to the fracture; and 4) continuing drilling through the formation using the NAF-based drilling fluid.
  • a NAF-based drilling fluid such as a hydrocarbon based or hydrocarbon containing drilling fluid
  • the present fluids may be used in methods of producing hydrocarbons from a well.
  • Exemplary methods may include: 1 ) drilling through a formation using a NAF-based drilling fluid to form a well, wherein a NAF filter cake is formed on at least one component of the well; 2) treating the at least one component of the well with an operations fluid comprising an organo-anionic surfactant and an alkyl acid, in water to remediate the NAF filter cake; and 3) producing hydrocarbons through the well.
  • FIG. 1 is a schematic representation of a subsurface region and associated production system
  • Fig. 2 is a schematic representation of a generalized organo-anionic surfactant
  • Fig. 3 presents representations of three exemplary organic amines that may be used in preparing the present organo-anionic surfactants
  • Fig. 4 presents representations of six exemplary acids that may be used in preparing the present organo-anionic surfactants
  • FIG. 5 is a schematic flow chart of methods herein;
  • Fig. 6 is an additional schematic flow chart of methods herein;
  • Fig. 7 is an additional schematic flow chart of methods herein;
  • Fig. 8 is an additional schematic flow chart of methods herein;
  • Fig. 9 presents exemplary data regarding permeability of a NAF filter cake following various treatment options
  • Fig. 10 illustrates a product cake following application of the present operations fluids
  • Fig. 1 1 illustrates a product cake following application of a conventional treatment fluid.
  • Figure-12 generally illustrates the effectiveness of some exemplary composition of FCR-FCS pill versus some comparative NAF formulations.
  • a subsurface region 100 and an associated production system 101 is illustrated in Fig. 1.
  • Fig. 1 and the other figures of the present disclosure are intended to present illustrative, but non-exclusive, examples according to the present disclosure and are not intended to limit the scope of the present disclosure.
  • the figures may not be drawn to scale, as they have been presented to emphasize and illustrate various aspects of the present disclosure.
  • the same reference numerals designate like and corresponding, but not necessarily identical, elements through the various drawing figures.
  • a floating production facility 102 is coupled to a well 103 having a subsea tree 104 located on the sea floor 106.
  • a control umbilical 1 12 may provide a fluid flow path between subsea tree 104 and floating production facility 102 with a control cable for communicating with various devices within well 103.
  • floating production facility 102 accesses a subsurface formation 108 that includes hydrocarbons, such as oil and gas.
  • Offshore production system 101 is shown for illustrative, non-exclusive purposes, and the present compositions and methods may be used in connection with the injection, extraction, and/or production of fluids into or from reservoirs or other formations at any subsurface location.
  • subsurface formation 108 To access subsurface formation 108, well 103 penetrates sea floor 106 to form a wellbore 1 13 bounding a well annulus 1 14 that extends to and through at least a portion of subsurface formation 108.
  • Subsurface formation 108 may include various layers of rock that may or may not include hydrocarbons and may be referred to as zones.
  • subsurface formation 108 includes a production zone, or interval, 1 16.
  • This production zone 1 16 may include fluids, such as water, oil, and/or gas.
  • Subsea tree 104 which is positioned over well annulus 1 14 at sea floor 106, provides an interface between devices within well annulus 1 14 and floating production facility 102. Accordingly, subsea tree 104 may be coupled to a production tubing string 1 18 to provide fluid flow paths and to a control cable 120 to provide communication paths, which may interface with control umbilical 1 12 at subsea tree 104.
  • Well annulus 1 14 also may include various casings, or casing strings, 122 and 124 to provide support and stability for access to subsurface formation 108.
  • a surface casing string 122 may be installed from sea floor 106 to a location beneath sea floor 106.
  • an intermediate or production casing string 124 may be utilized to provide support for the walls of well annulus 1 14.
  • Production casing string 124 may extend down to a depth near or through subsurface formation 108. If production casing string 124 extends to production zone 1 16, then perforations 126 may be created through production casing string 124 to allow fluids to flow into well annulus 1 14.
  • surface and production casing strings 122 and 124 may be cemented into a fixed position by a cement sheath or lining 125 within well annulus 1 14 to provide stability for well 103 and to isolate subsurface formation 108. Still alternatively, a portion of the well 103 may be left as an open hole with an exposed wellbore, or formation face.
  • FCS Fracture Closure Stress
  • DSF Drill Stress Fluid
  • a subsurface safety valve 128 may be utilized to block the flow of fluids from production tubing string 1 18 in the event of a rupture or break in control cable 120 or control umbilical 1 12 above subsurface safety valve 128.
  • a flow control valve 130 may be utilized and may be or may include a valve that regulates the flow of fluid through well annulus 1 14 at specific locations.
  • a tool 132 may include a sand screen, flow control valve, gravel packed tool, or other similar well completion device that is utilized to manage the flow of fluids from production zone 1 16 through perforations 126.
  • Packers 134 and 136 may be utilized to isolate specific zones, such as production zone 1 16, within well annulus 1 14.
  • the present compositions and methods are believed to be useful in remediating a NAF filter cake that may be accumulated on completion equipment or other downhole equipment, features, or surfaces.
  • the present compositions and methods may be used to remediate a NAF filter cake accumulated on an open hole wellbore face. Additionally or alternatively, the present compositions and methods are believed to be useful in altering the properties of the NAF filter cake to improve the hydrocarbon recovery operations.
  • compositions comprising an organo-anionic surfactant and an alkyl acids such as may be useful as a dispersant or surfactant.
  • the composition may have utility for use in hydrocarbon recovery operations, such as in drilling wellbores.
  • Surfactants and dispersants in the generalized sense of the terms, are well known and have been used separately in various forms in hydrocarbon recovery operations for a variety of purposes. While surfactants, generally, have been used for purposes including remediation of filter cake on downhole equipment, a review of the conventional compositions and methods reveals the conventional wisdom of such remediation methods: filter cake remediation requires the use of either a strong acid or a strong base.
  • the use of a strong acid provides the foundation for acid-based remediation efforts, using fluids such as sulfuric acid.
  • strong bases such as in the form of cationic surfactants, zwitterionic surfactants, and/or alkali-metal-based surfactants, form the foundation for conventional surfactant-based remediation efforts.
  • a conventional surfactant such as those formed from a strong base and a weak acid (i.e., a strong/weak surfactant)
  • the remediation fluids typically require a co-solvent, such as alcohols, to improve the solubility of the strong/weak surfactant, particularly in high salinity slurries or muds.
  • co-solvent increases the cost of the slurry, increases the complexity of the fluid make-up, and requires additional clean-up efforts. Additionally, many of the conventional, strong/weak anionic surfactants required the use of a co-surfactant, such as a non-ionic surfactant or a cationic surfactant, to form a micro-emulsion or nano- emulsion. Here again, the use of a co-surfactant increases costs, complexity, and clean-up requirements.
  • the conventional wisdom of surfactant-based remediation compositions and methods is analogous to cleaning methods in other fields where it is generally accepted that a strong base cleans better than a weak base and that a surfactant incorporating a strong base will be most effective at cleaning.
  • the organo-anionic surfactants of the present compositions and methods are formed by a weak base and a weak acid, forming what can be referred to as a weak/weak surfactant or, in the terms of the present disclosure, an organo-anionic surfactant.
  • a weak base as the building block for a filter cake remediation fluid is counter-intuitive based upon the prior literature and conventional technology, but has been found to be effective as a remediation fluid, as will be seen herein.
  • ⁇ R-X ⁇ ⁇ + ⁇ Y ⁇ which is generally illustrated in Fig. 2.
  • R is selected from the group comprising linear and branched alkyl and aryl alkyl hydrocarbon chains
  • X represents an acid selected from the group comprising sulfonic acids, carboxylic acids, phosphoric acids, and mixtures thereof
  • Y represents a weak organic base, such as an organic amine.
  • organic amines may be preferred.
  • Exemplary organic amines include monoethanol amine, diethanol amine, triethanol amine, ethylene diamine, propylene diamine, diethylene tri-amine, tri-ethylene tetra-amine, tetra ethylene pent-amine, dipropylene tri-amine, tripropylene tetra-amine, tetra propylene pentamine, and mixtures thereof.
  • the organic amine may be monoethanol amine, diethanol amine, triethanol amine, and mixtures thereof, such as illustrated in Fig. 3a-3c. More preferably, the organic amine is monoethanol amine.
  • Exemplary weak acids are illustrated in Figs. 4a-4f, which illustrates exemplary weak acids together with exemplary associated R groups.
  • the acid may be an organic acid, such as alkyl acids, alkyl aromatic acids, and mixtures thereof.
  • exemplary organic acids may include alkyl carboxylic acids, aromatic carboxylic acids, alkyl sulfonic acids, aromatic sulfonic acids, alkyl phosphoric acids, aromatic phosphoric acids and mixtures thereof.
  • a simple combination of the organic amines of Fig. 3 with the weak acids of Fig. 4 illustrates a representative family of eighteen organo-anionic surfactants within the scope of the present disclosure. Based on the representative acids and bases described here, the number of available organo-anionic surfactants is potentially very large.
  • organo-anionic surfactants While a variety of organo-anionic surfactants are within the scope of the present disclosure, they all have one feature in common.
  • the organo-anionic surfactants of the present disclosure comprise an anionic acid whose counter ion is a mono-, di-, or tri-ethanol ammonium cation.
  • Organo-anionic surfactants of the instant invention are prepared by contacting a weak acid, such as an organic acid or other acid described above, with a weak base, such as an organic amine or other base described above. Contacting can be done at any temperature preferably in the range of -50°C to 200°C. The preferred temperature range for the acid-base reaction will depend on the choice of weak acid and weak base. The amount of base that is used in the reaction may be equal to the molar equivalent of the weak or organic acid or may be less than the molar equivalent of the weak or organic acid.
  • the weight ratio of base: acid is 2:1. In the case of less than the molar equivalent, the weight ratio of base: acid is ⁇ 2:1 , for example 1.5:1 , 1.25:1 , 1 :1 , 0.75:1 , 0.5:1 and so on.
  • the organo-anionic surfactant is formed by contacting the weak base with the weak acid. In some implementations, the organo-anionic surfactant may be formed by contacting a neat base with a neat acid.
  • the resulting organo-anionic surfactant may then be incorporated into an aqueous fluid and/or a non-aqueous fluid.
  • each of the weak base and the weak base may be dissolved in separate aqueous solutions that are then mixed to contact the base and the acid to form the organo-anionic surfactant in an aqueous solution.
  • the aqueous solution of formation may then be incorporated into other aqueous fluids and/or non-aqueous fluids for use in hydrocarbon recovery operations.
  • the present disclosure provides a fluid for use in hydrocarbon recovery operations, such as on wells associated with hydrocarbon production.
  • the fluid may be aqueous fluids or non-aqueous fluids.
  • the aqueous fluids comprise water and at least one organo-anionic surfactant.
  • the aqueous fluid may be incorporated into a variety of stages of the hydrocarbon recovery operations and may be incorporated into a variety of slurries, muds, fluids, etc. (e.g., including non-aqueous slurries).
  • the aqueous fluid may be incorporated into drilling fluid, treatment fluid, injection fluid, treatment pills, etc.
  • the non-aqueous fluids described herein comprise a non-aqueous fluid and at least one organo-anionic surfactant.
  • the non-aqueous fluids incorporating the organo-anionic surfactant(s) may be used in a variety of fluids and slurries and may be used in a variety of operations.
  • Non-aqueous fluids incorporating the present organo-anionic surfactants may incorporate the neat surfactant and/or may incorporate an aqueous solution of the surfactant, such as by emulsification and/or micro-emulsification.
  • fluids incorporating organo-anionic surfactants will be referred to generally as operations fluids regardless of the type of operation in which the fluid will be used or the type of fluid being use (e.g., aqueous, non-aqueous).
  • Fig. 5 illustrates a simplified flow chart of methods 500 within the scope of the present disclosure. As illustrated, the methods 500 may begin by obtaining a weak acid 502 and obtaining a weak base 504. As can be understood from the discussion above, the acid and the base can be obtained at the same time or in any suitable order, as suggested by their positions in the flowchart of methods 500. As illustrated in Fig. 5, the methods continue by combining the acid and the base to form the organo-anionic surfactant at step 506.
  • the organo-anionic surfactant is then added to an operations fluid at step 508.
  • the organo-anionic surfactant may be added to virtually any type of fluid used in hydrocarbon recovery operations.
  • Exemplary, non-exhaustive, fluid types to which the organo-anionic surfactants may be added are listed in box 510.
  • the methods 500 continue at 512 by performing at least one hydrocarbon recovery operation with the operations fluid.
  • Box 514 provides illustrative, non-exhaustive examples of operations that may be performed using the operations fluids of the present disclosure (i.e., fluids comprising organo-anionic surfactants).
  • the ratio of organo-anionic surfactant in the operations fluid may vary depending on the application of the operations fluid and the stage in which it is being used in the hydrocarbon recovery operations.
  • the organo-anionic surfactant may comprise greater than about 0.5 wt% and less than about 50 wt%, based on the combined weight of the drilling fluid.
  • the composition of the operations fluid may vary over time, such as having a greater percentage of the present organo-anionic surfactants early in the operation stage and decreasing over time.
  • the present organo-anionic surfactants have the advantage of altering the properties of the NAF filter cake, such as by remediating the NAF filter cake to improve or restore permeability.
  • the organo-anionic surfactant(s) may constitute a larger percentage of the operations fluid initially to change the permeability (or otherwise modify the NAF filter cake) and then constitute a smaller percentage while the other components of the operations fluid are performing their functions, such as isolating the fracture to prevent lost returns.
  • the operations fluid may comprise an organo-anionic surfactant and water or mixtures of organo-anionic surfactants and water.
  • concentration of the organo-anionic surfactant may be greater than about 0.01 wt% and less than about 12 wt%, based on the weight of water.
  • the concentration of the organo-anionic surfactant may be greater than about 0.01 wt% and less than about 5 wt%, and more preferably the concentration may be greater than about 0.01 wt% and less than about 2 wt%.
  • the organo-anionic surfactant is selected from a monoethanol ammonium alkyl aromatic sulfonic acid, monoethanol ammonium alkyl carboxylic acid, and mixtures thereof.
  • the surfactants incorporated into the operations fluid may incorporate different alkyl groups.
  • the surfactants may incorporate alkyl groups having a variety of chain lengths or a variety of numbers of carbon atoms, such as greater than about 6 carbon atoms and less than about 18 carbon atoms.
  • the alkyl groups may have chain lengths greater than about 9 carbon atoms and less about 14 carbon atoms. More preferably, the alkyl groups may be a mixture having greater than about 10 carbon atoms and less than about 14 carbon atoms. Most preferably, the mixture has at least 50% of the surfactant comprising 12 carbon atoms on the alkyl groups.
  • the number of carbon atoms on the alkyl group of the organo-anionic surfactant is equal to the average number of carbon atoms per molecule of the non-aqueous drilling fluid being targeted by the surfactant.
  • the NAF filter cake is comprised primarily of molecules having 12 carbons, such as dodecane
  • the organo-anionic surfactant or mixture of organo-anionic surfactants has an alkyl chain with an average carbon chain length of 12.
  • a combination of surfactants having alkyl chain lengths including lengths of 1 1 , 12, and 13 could be combined for an average chain length of 12.
  • organo-anionic surfactant and/or the combination of organo-anionic surfactants has an average alkyl chain length corresponding to the chain length of the corresponding NAF fluid, it is referred to herein as "alkyl chain matched.”
  • alkyl chain matched organo-anionic surfactant and/or an alkyl chain matched mixture of organo ionic surfactants may be preferred in treating or otherwise remediating the NAF filter cakes.
  • Such alkyl chain matched surfactants have unique and unexpected performance advantages such as very low concentration requirements to attain high performance.
  • the operations fluid including the organo-anionic surfactant(s) may further comprise dissolved salts, such as chloride and sulfate salts of calcium and potassium.
  • dissolved salts such as chloride and sulfate salts of calcium and potassium.
  • the operations fluid when the operations fluid is an aqueous fluid comprising organo-anionic surfactants, the aqueous fluid may contain a variety of additives common to aqueous fluids used in hydrocarbon recovery operations; dissolved salts is but one example.
  • the amount of dissolved salts, when included, may be greater than about 0.01 wt% and less than about 25 wt%, based on the weight of water. Preferably, greater than about 0.01 wt% and less than about 5 wt%.
  • the operations fluid may further comprise alcohols such as methanol, ethanol, propanol, butanol, pentanol, hexanol, heptanol, octanol and mixtures thereof.
  • the alcohols when included, may be greater than about 0.001 wt% and less than about 15 wt%, based on the weight of water.
  • the compositions of the present disclosure in contrast to the conventional surfactants, do not require alcohols.
  • the aqueous fluid including the organo-anionic surfactant(s) may further comprise organic acids, such as greater than about 0.001 wt% and less than about 6 wt%, based on the weight of water. Preferably, greater than about 001 wt% and less than about 3 wt%, based on the weight of water.
  • organo-anionic surfactant may be added to aqueous and/or non-aqueous fluid(s) to improve drilling operations, completion operations, clean-up operations, production operations, injection operations, and/or treatment operations.
  • compositions, operations, advantages, and functionality are described for both non-aqueous fluids comprising organo-anionic surfactant(s) and aqueous fluids comprising organo-anionic surfactants, the operations, advantages, and functionality of any specific composition (e.g., non-aqueous and/or aqueous compositions) may be common to other compositions described herein.
  • compositions described herein are believed to provide one or more of the following advantages by virtue of incorporating the organo- anionic surfactant(s): 1 ) the oil uptake effectiveness and efficiency of the fluids comprising organo-anionic surfactant(s) is higher than comparable fluids comprising alkali metal anionics for a given concentration and salinity; 2) the organo-anionic surfactants provide formulation flexibility and cost advantages and can be formulated over a wider range of water salinity; and 3) the organo-anionic surfactant(s) can be formulated into hydrocarbon recovery fluids with a single family of surfactants, such as not requiring the use of additional non-ionic co-surfactants or co-solvents.
  • organo- anionic surfactants when the organo- anionic surfactants are incorporated into operations fluids that are applied to treat existing NAF filter cakes, it is observed that the existing NAF filter cake may change from oil wetting to water wetting, and, when the operations fluid is an aqueous fluid, the operations fluids may extract non-aqueous fluid from the NAF filter cake. Either or both of these functions may remediate the NAF filter cake to changes its properties, such as its permeability, its elasticity, etc.
  • Other advantages, features, and functionality described herein in the context of one or more exemplary compositions may be found in other compositions described or claimed herein.
  • organo-anionic surfactants may be in the treatment of lost returns problems, such as in conjunction with FCS and/or DFS methods.
  • the organo-anionic surfactant may be incorporated into a treatment pill that is pumped prior to the delivery or pumping of the FCS pill, may be incorporated into a treatment pill that is pumped during the DFS methods, and/or may be incorporated directly into the fluids that comprise the FCS pill or treatment fluids.
  • these methods of treating lost returns depend in part on the permeability of the fracture faces and the ability of the carrier fluids to leak off quickly to trap the FCS solids in the fracture.
  • the presence of the organo-anionic surfactant in the NAF composition of a drilling operation such as a DSF drilling operation, will result in a NAF filter cake having improved permeability rendering the DSF methods more effective.
  • an operations fluid containing organo-anionic surfactants to an existing NAF filter cake is effective at remediating the NAF filter cake, such as restoring permeability, reducing elasticity, changing wettability, and facilitating the clean up and/or removal of the filter cake, such as from the formation and/or the completion equipment.
  • the NAF filter cake may be disposed on at least one of a facture face, a sand screen, gravel pack components, and a wellbore wall.
  • the volume of operations fluid containing organo-anionic surfactants may be pumped downhole to contact these features and to breakup or otherwise remediate the NAF filter cake.
  • a relatively small amount of operations fluid containing organo-anionic surfactants may be effective in treating or remediating the filter cake.
  • the volume of operations fluid and the concentration of organo-anionic surfactants incorporated therein may vary. Exemplary concentrations of the organo-anionic surfactant in the aqueous portion of the operations fluid may be as described above.
  • the volume of operations fluid may significantly increase.
  • the volume of operations fluid required to remediate the NAF filter cake may depend on factors such as the location of the filter cake, the nature of the filter cake, the extent of filter cake needed to remediate, the permeability of the formation, the likelihood of thief zones, etc. Accordingly, while a specific volume of operations fluid may be definable for a given implementation, the present methods are best understood as applying or pumping a volume of operations fluid comprising organo-anionic surfactants into the well to remediate or treat the NAF filter cake.
  • aqueous treatment fluids comprising the present organo-anionic surfactants may be used as an operations fluid in an FCS-based lost returns treatment.
  • Fig. 6 is an exemplary flow chart of methods 600 of treating lost returns in a well including a fracture. As depicted in the flow chart, an operator is engaging in drilling operations 602 and forming a filter cake 604 when a fracture forms in the wellbore 606. It is worth noting that the filter cake forms on the wellbore wall and on the face of the fracture. The operator may then determine whether treatment is needed, at 608, such as if there is a lost returns problem.
  • the operator may begin the treatment by injecting, as illustrated at box 610, an aqueous treatment fluid comprising organo-anionic surfactant(s), as described herein, before continuing the drilling operations, at 618.
  • the treatment process includes injecting proppants, at 614, into the fracture while leaking off carrier fluids to deposit FCS proppants in the facture and while increasing the circulating pressure in the wellbore above the fracture pressure. The pressure may be increased to increase the fracture closure stress, or the integrity, of the formation.
  • the fracture closure stress is sufficiently elevated, at 616, the drilling operations may continue, such as at 618.
  • the process may continue by returning to determining whether another treatment should be applied, as at 608. This method continues until the well is drilled to the desired depth.
  • some methods of utilizing the present fluids comprising organo-anionic surfactants may proactively prevent lost returns by intentionally fracturing the wellbore at strategic times to apply an FCS process, or other suitable process to increase the integrity of the formation.
  • the strategic, intentional formation of a fracture may allow the operator to better time the treatment operations to avoid substantial lost returns and/or to utilize the treatment equipment and fluids on a preferred schedule rather than in response to unexpected lost returns incidents.
  • Fig. 7 is an exemplary flow chart of methods 700 for strategically applying FCS treatments utilizing organo-anionic surfactants.
  • the drilling operations begin at 702 and a filter cake forms at 704, such as would occur when drilling with a NAF drilling fluid.
  • a fracture may be desired, at 706, for a variety of reasons, such as to intentionally apply an FCS process to increase the integrity of the wellbore.
  • the present technology provides at least two options, as illustrated in Fig. 7.
  • the operator may mix organo-anionic surfactants with an FCS pill, at 708, or the operator may treat the wellbore, or a targeted section of the wellbore, with an aqueous treatment fluid comprising organo-anionic surfactant(s), at 710, to remediate the NAF filter cake, at 71 1.
  • An operator may then inject the FCS pill into the wellbore at 712.
  • the injection of the FCS pill may be conducted so as to induce a fracture, as at 714, into which an immobile mass is deposited, such as from the solids or particulates in the FCS pill.
  • the methods 700 may increase the circulating pressure in the wellbore to increase the FCS of the formation or wellbore until the FCS is sufficient to continue drilling, at 716.
  • it may be preferred to induce the fracture before injecting the FCS pill.
  • the injection of the FCS pill 708 and/or the remediation of the NAF filter cake 71 1 may increase the permeability of the formation sufficiently to make it more difficult to induce a fracture.
  • organo-anionic surfactants and fluids containing the same may also be adapted to address problems associated with differential pressure sticking (DPS).
  • DPS differential pressure sticking
  • Filter cakes formed in a well, whether NAF-based or otherwise, may cause the well tool or pipe to "stick" in the wellbore.
  • the NAF filter cakes are less likely to encounter this problem, but it may still occur.
  • the organo-anionic surfactants of the present disclosure may be utilized to remediate the NAF filter cake, decreasing its volume and/or increasing its permeability to free a differentially stuck pipe or well tool.
  • the organo-anionic surfactants of the present disclosure are effective at both breaking up the NAF filter cake and increasing the permeability of the filter cake.
  • Fig. 8 is an exemplary flow chart of preferred methods 800 of treating differential pressure sticking of a well tool.
  • the operator may be conducting drilling operations 802, thereby forming a filter cake 804 in the well such that the well tool is stuck 806 by differential pressure sticking.
  • the operator may then inject, at 808, a treatment fluid comprising organo-anionic surfactant(s) to increase the filter cake permeability and/or break up the filter cake.
  • the operator may allow the treatment fluid to soak for a time before pulling or moving the tool until free, at 810. Once the tool is free, the drilling operations (or other operations) may be continued as planned, at 812.
  • the period of time required for the soak may vary depending on the nature and extent of the filter cake, the degree to which the tool is stuck, the quantity and concentration of treatment fluid used, etc. Additionally or alternatively, the operator may periodically attempt to manipulate the pipe or tool to free it without a predetermined soak period.
  • the present disclosure may be understood as an organo-anionic surfactant in an aqueous fluid that forms part of an operations fluid, the present disclosure may also be understood as being directed to an organo-anionic surfactant incorporated into a nonaqueous fluid for use in hydrocarbon recovery operations, such as in a NAF-based drilling fluid, a NAF-based treatment fluid, a NAF-based completion fluid, etc.
  • the concentration of the organo-anionic surfactant in the NAF composition may be greater than about 0.01 wt% and less than about 30 wt%, based on the weight of non-aqueous fluid in the NAF composition.
  • the NAF composition may be any suitable composition, such as those compositions that are conventionally used in hydrocarbon recovery operations.
  • Exemplary non-aqueous fluids into which the organo-anionic surfactants may be incorporated may comprise linear, branched, or cyclic alkanes; linear alpha olefins, branched olefins, cyclic olefins; esters synthesized from linear, branched, or cyclic alkane acids; and linear, branched, or cyclic alcohols; mineral oil hydrocarbons; bioesters, such as but not limited to glyceride mono-, di-, and tri-esters, derived from plants and animals, including olive, coconut, canola, castor, corn, cotton seed, rapeseed, lard, and soybean oils and mixtures and combinations thereof.
  • the NAF composition may further comprise, in addition to the organo-anionic surfactant, one or more of: at least one emulsifier, at least one weighting agent, at least one rheology modifier, at least one filtration control agent, and/or other conventional additives to NAF compositions that are common in hydrocarbon recovery fluids.
  • composition and relative amounts of each component may vary between the various applications of NAF compositions in which the present organo-anionic surfactants may be incorporated.
  • the manner in which the organo-anionic surfactant is incorporated in the NAF composition may vary.
  • a neat surfactant made from contacting a neat acid and a neat base, may be mixed directly in the non-aqueous fluid.
  • the organo-anionic surfactant may be incorporated into an aqueous fluid that is then incorporated into the non-aqueous fluid, such as by emulsification and/or micro-emulsification.
  • the aqueous fluid may be according to any of the description herein of aqueous fluids comprising organo-anionic surfactants.
  • the amount of aqueous solution incorporated into the non-aqueous fluid may be limited by emulsification principles and the intended utility and final composition of the non-aqueous fluid.
  • the organo-anionic surfactant(s) may comprise greater than about 0.01 wt% and less than about 20 wt% based on the weight of the non-aqueous fluid. Preferably, greater than about 0.01 wt% and less than about 10 wt%.
  • the organo-anionic surfactant(s) disclosed herein imparts one or more unique properties to the non-aqueous fluid composition.
  • One such property is that the NAF composition forms NAF filter cakes of low elasticity. Having the ability to control filter cake elasticity has advantages in many reservoir processes such as but not limited to (i) improved well bore clean up, (ii) improved injectivity, and (iii) remediating damage to gravel pack and screen productivity.
  • the organo-anionic surfactants are believed to facilitate the removal of filter cake as a well is transitioned from drilling and completions mode to production mode.
  • the NAF composition invades the pore spaces adjacent to the borehole and deposits material to form "internal filter cake.” It also deposits material on the surface of the borehole to form "external filter cake.”
  • filter cake will include both the internal and external filter cake, except where specifically indicated otherwise.
  • the depth of invasion and character of the filter cake formed depend on a variety of factors, including the components of the NAF compositions, the size of the pore throats relative to the mud solids, the differential pressure driving the flow, the effectiveness of the filter cake deposited on the face of the borehole, and any ionic or surface tension interaction between the fluid and pore channels.
  • the filter cake is expected to lift off, such as by the flow of formation fluids into the wellbore or by the action of a treatment fluid.
  • many of the treatment fluids desirably used are aqueous fluids.
  • An oil-wet NAF filter cake is generally not well treated by aqueous treatment fluids.
  • the present organo-anionic surfactants may alter the wettability of a NAF filter cake from oil- wetting toward water-wetting, rendering conventional (including aqueous-containing) cleanup treatment fluids more effective.
  • NAF filter cakes exhibit elasticity due to the interfacial tension interactions between the solids and the oils. Additionally, it has been observed that elastic filter cakes resist movement through the rock. If the elastic resistance is high, the filter cake remains in place and production rates (or other operations) are adversely impacted. This elastic effect further compounds the negative effects caused by filter cake during production operations.
  • skin or “skin damage,” or “skin effect,” or similar terms.
  • a skin grade or factor of 0 indicates there is substantially no noticeable damage or limitation, and production or injection rates are as expected primarily due to formation properties. In wells drilled with NAF, the skin factor typically grades in the range of 1-3, so there is quantifiable evidence (such as by observed poor production or injection rates) that remediation may be needed.
  • the degree to which this near-wellbore formation damage or skin occurs can be reduced by drilling with the NAF of the present disclosure, incorporating a combination of organo-anionic surfactants.
  • the disclosed NAF compositions form or enable filter cakes that exhibit low or reduced filter cake hydrocarbon-formation interfacial tension elasticity, resulting in improved permeability to either aqueous-containing wellbore fluids, and/or formation fluids.
  • the presently disclosed NAF filter cake treatment compositions may also even allow at least a portion of the filter cake to be removed flow back out of to the wellbore during a cleanup or production operations, following treatment by a fluid composition according to the present disclosure.
  • the present organo-anionic surfactants may be incorporated into operations fluid for altering the properties of the filter cake being formed and/or to treat existing filter cakes.
  • treatment fluids incorporating the organo- anionic surfactants described herein may be applied, for example (but not limited to): operations such as a remedial treatment such as during drilling or completion operations; a pre-treatment associated with completion or cementing operations; concurrently with the conventional wellbore clean-up fluids; or even post-completion after production has commenced to attempt to remove previously existing skin damage.
  • An example of a suitable implementations for the presently disclosed formulations pertains to NAF drilling operations, such as drilling or preparing a wellbore that has been exposed to NAF-type operations fluid and has experienced a lost circulation problem, such as while drilling.
  • the presently disclosed fluids may be used as part of a remediation operation, and may include organo-anionic surfactants within a composition such as discussed herein.
  • the organo-anionic surfactants may improve filter cake permeability, which ultimately may result in either improved filter cake creation, or reduced filter cake elasticity for filter cake removal, and/or improved filter cake permeability such as for stimulation fluid permeation, or to facilitate improved permeability for production or injection operations.
  • the effectiveness of a production or injection operation depends in part on the ability of the produced or injected fluid to pass through the remaining filter cake, through the near-wellbore formation face, and through the earthen formation.
  • the formation pores may become plugged or damaged by NAF filter cakes and/or skin damage.
  • Use of an NAF fluid composition that incorporates organo-anionic surfactant(s) and fluid compositions such as disclosed herein is used as the drilling or operation fluid, (or other operation fluid that forms the filter cake), the resulting NAF-based filter cake may exhibit beneficially improved, controlled, or reduced elasticity, such as described above.
  • elastic NAF filter cakes reduce the injectivity of the injected fluids in much the same way the elastic NAF filter cake reduces the productivity of formation fluids, by limiting the mobility of the solids that form the filter cake.
  • the flow must occur through both the NAF filter cake on the borehole wall, as well as the internal elastic NAF filter cake in the formation fractures and pore spaces. Limited injection rates may be experienced. Due to the limited number of disposal wells available and/or the specific needs for injection in stimulation treatments, the limited injection rates in regions of the well where injection is needed may have dramatic consequences for hydrocarbon production rates for the well and/or field associated with the present wellbore.
  • a secondary recovery type injection well intended to introduce fluids to move hydrocarbons towards a production well may be rendered ineffective (for its intended purpose) if the injectivity of the well or of a segment of the well is sufficiently limited.
  • injectivity enhancement treatments are known to attempt to address this issue.
  • the purpose of injection is for reservoir pressure maintenance or secondary recovery, the consequences are significant. Some sections may receive fluid and others not, affecting the production profile from the entire reservoir.
  • the degree to which injectivity damage, such as that caused by the presence of an elastic NAF filter cake, occurs can be reduced by drilling with the NAF operations fluids disclosed herein incorporating organo- anionic surfactants.
  • the disclosed NAF operations fluids incorporating organo-anionic surfactants form filter cakes of low elasticity so that impact on injectivity is minimized and injectivity enhancement treatments are effective.
  • the operations fluids herein may be adapted to provide a pre-treatment to alter the wettability of the NAF filter cake and/or to extract non-aqueous fluid from the NAF filter cake.
  • the present compositions including organo-anionic surfactants may be useful in remediating gravel packs and screens following completion operations.
  • Well completions are generally designed to prevent the collapse of sand formations that are unstable under flowing conditions and to prevent the flow of formation sand into the production casing, among other reasons. This may be accomplished by packing the area between the casing and borehole with additional permeable sand to hold the borehole open, or to screen out any native sand that becomes free to travel with the inflow. This packing is referred to as a "gravel pack.”
  • Various forms of screens or slotted pipe are then used to prevent the gravel pack itself from flowing into the casing. In some cases, there is no gravel pack required and fine screens alone are used to prevent the influx of native sand.
  • NAF filter cake invades the formation while drilling, or if the NAF filter cake remains after the gravel pack operation, or if a NAF filter cake is formed during the completions operations, such as by using a NAF fluid to place the gravel pack, the NAF filter cakes must then flow back through the gravel pack or screens.
  • the return flow of the filter cake is related to the size distribution of the particles from the filter cake relative to the openings between the sand grains or in other completion equipment or systems.
  • the elasticity of the NAF filter cake has been seen to have an impact on the return flow of the filter cake.
  • the openings are typically about 200 microns in size.
  • the particles in the NAF filter cake are typically less than 100 microns, so they should be able to pass through without plugging the screens. However, it is observed that screens do become plugged with NAF filter cake in field operations. This observation is explained by the current recognition of the NAF filter cake as an elastic material comprised of oil and solids.
  • the elasticity of NAF filter cakes that may limit productivity can be reduced.
  • the disclosed NAF operations fluids incorporating organo- anionic surfactant(s) forms filter cakes of low elasticity, which contributes to performance.
  • the particulates of the filter cake can be flowed back through the gravel pack and/or screens more readily, by formation fluids and/or treatment fluids.
  • the use of the present operations fluids, and specifically aqueous fluids incorporating organo-anionic surfactants may be used to alter the properties of the filter cake to make it water wetting to facilitate conventional filter cake treatments.
  • the application of the present operations fluids may improve the permeability of the NAF filter cake sufficiently that production rates are acceptable.
  • the skin may be reduced from a grade of 3 to a grade of 1.
  • the organo-anionic surfactants may be incorporated into the NAF operations fluids to alter the properties of the resulting NAF filter cake, the organo-anionic surfactants may be used in an aqueous fluid or a non-aqueous fluid as a remediation or treatment fluid, such as in a treatment pill that may be pumped during a drilling operation or as part of a remediation or workover operation. Exemplary implementations of organo- anionic surfactants as treatment fluids were described above in various contexts.
  • organo-anionic surfactants into NAF compositions and into aqueous treatment fluids for use before and/or during a variety of hydrocarbon recovery operations and the extension of the present compositions in other hydrocarbon recovery operations in other manners should not be limited by the exemplary implementations described herein. In the interest of clarity and conciseness, the present application is limited to these few representative but non-limiting examples.
  • a first organo-anionic surfactant referred to as OA-Surf-1
  • OA-Surf-1 a first organo-anionic surfactant, referred to as OA-Surf-1
  • a filter cake was prepared from an oil based mud using a high pressure high temperature filter press fitted with a 35 micron aloxite filter.
  • 50 ml of an oil based mud (OBM-1 ) was added to the filter press and the sample heated to 200°F.
  • a pressure of 800 psi was applied to the heated sample using nitrogen gas as the pressurizing gas and filtration started. After 30 minutes of filtration about 5 ml of clear oil was obtained as the filtrate.
  • the cell was depressurized to ambient pressure and cooled to 100°F.
  • the excess unfiltered OBM-1 was decanted off. This procedure generated an OBM-1 filter cake.
  • the treatment fluid comprising an organo-anionic surfactant was then prepared.
  • the treatment fluid was an aqueous solution having 2 wt% organo-anionic surfactant and 0.3wt% NaCI.
  • the organo-anionic surfactant for this example was mono- ethanol ammonium dodecyl benzene sulfonate.
  • this treatment fluid solution was added to the filter press containing the OBM-1 filter cake.
  • the filter cake was contacted with the treatment solution and the temperature of the solution and cake held at 200°F at 800 psi for about 2.5 hours. After treatment with the surfactant solution the filter cake produce a remediated filter cake.
  • the remediated filter cake was then contacted with a high fluid loss water based mud configured after the manner of a conventional FCS pill.
  • the FCS pill had the following components: 4.29wt% Attapulgite clay, 4.29 wt% diatomaceous earth, 0.14 wt% Xanthan gum, and 31 .42 wt% walnut hull (e.g., ground walnut shells), wherein all weight percents are based on the weight of water.
  • the FCS pill was held at 200°F and 800 psi; the water from the FCS pill was allowed to filter through the remediated filter cake.
  • the volume of filtrate as a function of time was noted, and is illustrated in Fig. 9.
  • the filter press was cooled and depressurized.
  • the product of the three step process (called product cake) is shown in Fig. 10.
  • the aloxite filter was removed leaving the filter cake 1010 and the solid components of the filtered portion of the FSC pill. These filtered solid components of the FCS pill may be referred to as the product cake 1012.
  • the height 1014 of the product cake 1012, from the side of the filter cake, was measured. In this example, the height 1014 of the product cake 1012 was 1 .8 centimeters.
  • OA-Surf-2 a different organo-anionic surfactant, referred to as OA-Surf-2, was used in the steps described above.
  • the amount of filtrate was measured and is shown in Fig. 9; the height of the filter cake was 1 .5 centimeters.
  • alkali-metal anionic surfactant a strong base, weak acid surfactant
  • the alkali-metal anionic surfactant was sodium dodecyl benzene sulfonic acid (NA-DBS).
  • NA-DBS sodium dodecyl benzene sulfonic acid
  • the product cake 1 1 12 formed using NA-DBS in the FCS pill is illustrated in Fig. 1 1 on top of the filter cake 1 1 10.
  • the filtrate volume as a function of time is shown in Fig. 9 and the height 1 1 14 of the product cake was 0.4 centimeters.
  • the heights of the product cakes are aggregated in the following table for convenience.
  • the treatment fluids comprising organo-anionic surfactant(s) of the present disclosure are able to remediate the filter cake three to four times better than the conventional treatment fluids using alkali-metal anionic surfactants.
  • the conventional treatment fluids are formed using strong bases while the present organo-anionic surfactants use weak bases, the dramatic improvement in remediation ability is counter-intuitive.
  • the operation fluid described above may be further modified for enhanced filter cake remediation, generally by adding an alkyl acid to the operation fluids described above.
  • a filter cake remediation (FCR) surfactant or FCR operations fluid Such embodiments may be referred to herein as a filter cake remediation (FCR) surfactant or FCR operations fluid.
  • the FCR operations fluid and/or FCR treatment may be combined with or added to a fracture closure stress (FCS) operations fluid (such as but not limited to, as described above) and/or treatment operation, to form a modified operations fluid comprising or utilizing the combination (combined into a common treatment fluid and/or sequentially applied treatment fluids) of surfactant-type fluids.
  • FCS fracture closure stress
  • a filter cake remediation (FCR) surfactant solution may comprise water, at least one organo-anionic surfactant (functioning as a wetting agent surfactant, as discussed above) and an alkyl acid (functioning as a hydrocarbon dispersant type surfactant, discussed below).
  • the alkyl acid includes at least one of an alkyl carboxylic acid, alkyl sulfonic acid, alkyl aromatic carboxylic acid, alkyl aromatic sulfonic acid, and mixtures thereof.
  • alkyl acid is an alkyl aromatic sulfonic acid.
  • the aromatic group of the alkyl aromatic sulfonic acid can be a 1 -ring or 2-ring aromatic group or mixtures thereof.
  • the aromatic group may also be a benzene, xylene, or similar group.
  • the alkyl group of the alkyl acid preferably has between 8 to 18 carbon atoms, more preferably between 10 to 14 carbon atoms.
  • the alkyl chain can be a linear hydrocarbon chain or a branched hydrocarbon chain or mixtures thereof.
  • the alkyl acid may be present in an aqueous solution preferably at a concentration in the range of 0.5 to 10 wt% based on the weight of water in the aqueous solution.
  • the FCR surfactant solution when combined with a conventional FCS pill exhibited an unexpectedly high degree of success in remediating a NAF filter cake. Also surprisingly, the presence of the FCR surfactants did not alter the favorable performance properties of the FCS pill. Although some treatment formulations or application may benefit from sequential treatment by the FCR operations fluid and then the FCS operations fluid, in many applications, the need to first remediate the NAF filter cake with merely an organo- anionic surfactant and then treat with an FCS pill is often unnecessary with use of the combined FCR-FCS operations fluid treatment combination. The addition of the alkyl acid to the organo-anionic surfactant enables effective use of the combined FCR-FCS operations fluid or treatment pill.
  • the FCR-FCS combination also solves the long standing need for treatment of a high fluid loss problem in an NAF-containing wellbore or a wellbore containing an NAF filter cake.
  • the following experiments and examples illustrate the surprising effectiveness of some exemplary embodiments of FCR-FCS operation fluid pills.
  • LAB TEST EXAMPLES A non-aqueous based NAF (invert emulsion, Carbo- DrillTM from BHDFTM, an invert emulsion system that typically uses diesel or mineral oil) was used as the test wellbore fluid to create a simulated wellbore filter cake was used for the tests.
  • the test fluid had a mud weight of 10.2 ppg and an hydrocarbon-water ratio of 81 .
  • a high fluid loss FCS treatment pill was prepared with the following components: 4.29wt% Attapulgite clay, 4.29 wt% diatomaceous earth, 0.14 wt% Xanthan gum, and 31 .42 wt% walnut hull, wherein all weight percents are based on the total weight of fluid system with all components included.
  • a commercially available composition referred to herein as a "cement spacer" due to a common use for such composition, comprising primarily a mixture of terpene and hydrocarbon solvent was used for a comparative experiment.
  • a 100 mL quantity of FCR pill solution was prepared by adding 2g of organo-anionic surfactant R-X-Y and 2g of dodecyl benzene sulfonic acid (alkyl acid) to 100 mL of water and thoroughly mixing the same.
  • Aloxide filter disks Part # 170-53; 50 micron pore size), were purchased from OFITE Company, Houston, Texas, USA, for the tests.
  • Filter Cake Treatment with Cement Spacer Solution (Comparative "Pretreatment Control Experiment"): 10 ml of neat undiluted cement spacer solution was added to the HTHP cell with a filter cake disk as a pre-treatment solution, followed by addition of 50ml of the FCS pill to determine whether the cement spacer might improve FCS pill effectiveness. Filtration was conducted at 100°F and 800 psi. The lower temperature, 100°F, was selected for safety reasons, as the flash point of the cement spacer solution is reported to be about 124°F. The volume of liquid filtering from the cell was recorded every 5 minutes. After 2 hours the unit was depressurized and disassembled. The unfiltered FCS pill was recovered from the HTHP cell and the filter disk removed.
  • Exemplary FCR-FCS Pill Treatment The FCR-FCS pill solution comprised 50 ml of the FCS pill solution and 10 ml of the FCR surfactant solution, prepared as described above. The FCR solution was added to the FCS solution and mixed to provide the combined, FCR-FCS pill. The FCR-FCS pill was added to a non-pretreated filter cake in the HTHP cell, mixed for 5 to 10 minutes at 300 to 600 rpm with a paddle type mixer and then filtered at 200°F and 800 psi for 2 hours. The volume of liquid filtering from the cell was recorded every 5 minutes. After 2 hours, No unfiltered FCS pill was observed in the HTHP cell and the filter cake and disk were removed from the cell. Three separate trials of an FCR-FCS combination pill treatment were conducted, using essentially similar formulations.
  • the aqueous / water / non- hydrocarbon-based components of the treatment solutions should preferably leak-off relatively quickly to enable enhanced deposition of solids upon the filter cake, such that the built-up solids filter cake will then provide sufficient leak-off control with respect to a hydrocarbon-based or other NAF-based drilling fluid.
  • the enhanced solids buildup should help mitigate or prevent loss of operations fluid circulation during drilling or other activity, when such activity is commenced or continued after FCR-FCS treatment. It is noted that some hydrocarbon fluid may also leak off during early-time portions of the leak-off tests.
  • the initial hydrocarbons are being removed from the initial filter cake saturation and the leak-off rate of the hydrocarbon fluids should become curtailed as filtration continues and solids build-up occurs on the initial portion of the filter cake and as the hydrocarbon saturation in the initial filter cake becomes reduced.
  • the presently claimed and described operations fluid further alters the wettability of the initial portion of the filter cake thus enhancing the effective permeability of the initial filter cake to water or aqueous-based fluids, thereby enhancing solids deposition on the filter cake.
  • Figure 12 graphically illustrates filtrate leak-off volume (ml) versus filtration or leak-off time (minutes).
  • Line 100 demonstrates a control or comparative treatment composition, that when the filter cake was not pre-treated with the cement spacer fluid, as discussed above as the "untreated control experiment," only about 3ml or 6 vol% of the water from the FCS pill leaked off through the filter cake.
  • the filter cake remained mostly unaltered and its oily consistency and oil saturation substantially remained after treatment. Undesirably, the majority of the FCS pill solution was recovered from the HTHP test cell after the experiment.
  • the filter cakes were treated only with the combined FCR-FCS pill (no pre-treatment), according to the exemplary compositions of the subject operations fluid, as described previously.
  • Graphical curves 120, 130, and 140 clearly demonstrate that substantially all of the 50 ml of the FCR- FCS test fluid leaked off within 40 to 60 minutes. Approximately half of the fluid had leaked off within the first half-hour.
  • Three trials were performed with the FCR-FCS pill to evaluate reproducibility of performance results.
  • the filter cakes for all three FCR-FCS trials demonstrated substantial solids mass build-up on the original filter cake, substantially doubling or even tripling in filter cake thickness as compared to the cake thicknesses in each of the comparative experiments illustrated by curves 100 and 1 10.
  • the recovered filtrate from each of the exemplary trials included not only the water from the FCR-FCS pill but also included some hydrocarbon filtrate fluid from the original saturation of the filter cake. It may be concluded that the combined FCR-FCS pill not only altered filter cake wettability to enable water permeation there-through, but also substantially altered the hydrocarbon saturation as well by substantially flushing hydrocarbons from within the filter cake.
  • the presently claimed subject matter may also include an operations fluid for use in operations on wells associated with hydrocarbon production, the operations fluid comprising: water, at least one organo- anionic surfactant, and an alkyl acid.
  • Such operations fluid may be used to pre-treat a filter cake in a wellbore prior to introduction of solids to enhance the filter cake.
  • the operations fluid may be used substantially continuously during wellbore operations or circulation, such as to condition the existing filter cake to provide a desirable cake property, such as enhanced leak off, altered wettability, or other desired effect.
  • inventive operations fluid may be utilized or applied as a combined FCR-FCS treatment fluid or pill, or applied in separate stages, such as a first stage including one of the FCR or FCS components and another stage providing the other component.
  • the operations fluid may include other additives or components, such as the solids used to build filter-cake thickness.
  • the alkyi acid is selected from the group consisting of alkyi carboxylic acid, alkyi sulfonic acid, alkyi aromatic carboxylic acid, alkyi aromatic sulfonic acid, and mixtures thereof.
  • the alkyi group of the alkyi acid may preferably have a carbon bond length in a range of from 8 to 18 carbon atoms.
  • the alkyi acid may be present in solution at a concentration in the range of 0.01 to 20 wt%, or 0.01 to 10 wt%, or 0.01 to 6 wt%, or 0.5 to 10 wt%, based on the total weight of water in the FCR surfactant solution.
  • the operations fluid may further comprising solids selected from the group consisting of sand, clay, diatomaceous earth, organic solids, wellbore cuttings, particulate or solid lost circulation materials (LCM), and mixtures thereof.
  • the operations fluid may include solids (including but not limited to particulates) in the concentration range of 0.5 to 10 wt% attapulgite clay, 0.5 to 10 wt% diatomaceous earth and 5 to 80 wt% walnut hull, wherein all weight percents are based on the total weight of the FCS pill solution.
  • the operations fluid may also comprise other lost circulation controlling or rheological additives, such as at least one of xanthan gum, guar gum, another cellulose- based material, and mixtures thereof.
  • Other exemplary additives may include dissolved salts, wherein the concentration of dissolved salts is, for example, in a range of from at least 0.1wt% to not greater than 6.0wt%, based on the weight of water in the FCS pill solution.
  • the operations fluid adapted to remediate a non-aqueous fluid (NAF) filter cake by performing at least one of: (1 ) altering the wettability of the NAF filter cake from oil wetting to water wetting; and (2) dispersing or extracting non-aqueous fluid (e.g., hydrocarbons) associated with the NAF filter cake.
  • NAF non-aqueous fluid
  • the alkyi acid comprises at least one of alkyi carboxylic acid, alkyi sulfonic acid, alkyi aromatic carboxylic acid, alkyi aromatic sulfonic acid, and mixtures thereof.
  • alkyi aromatic acid and more preferably in some embodiments, alkyi aromatic sulfonic acid and even more preferably in still other embodiments, a dodecyl aromatic sulfonic acid, or a docecyl benzene sulfonic acid.
  • the organo anionic surfactant comprises at least one of monoethanol amine, diethanol amine, triethanol amine, and mixtures thereof.
  • the organo- anionic surfactant is typically present in the operations fluid at a concentration in a range of from at least 0.01 wt% to not greater than 12.0 wt%, or from 0.01 wt% to not greater than 3.0 wt%, based on the total weight of the water in the FCR surfactant solution.
  • the operations fluid of claim 1 further comprising a wellbore fluid that includes at least 20 wt%, or at least 40 wt%, or at least 50 wt%, or at least 60 wt%, or at least 80 wt%, of NAF, based upon the total weight of the wellbore fluid.
  • this invention also includes a treatment system for operations on wells associated with hydrocarbon production (e.g. , production wells, injection wells, disposal wells, etc.), the treatment system comprising: preparing a treatment pill comprising: water; at least one organo-anionic surfactant; an alkyl acid; and a particulate material; and placing the treatment pill into a wellbore associated with hydrocarbon production.
  • the treatment pill may be placed into the wellbore with each of the aforementioned components in a common pill, or may be placed into the wellbore in a sequence of steps, such as providing the liquid components in initial steps and the particulate material in subsequent steps.
  • the liquids and particulates may be placed into the wellbore in an essentially common application.
  • the pill may be placed into the wellbore by spotting the pill or by substantially continuously circulating a wellbore fluid laden with the subject operations fluid, either substantially during operations or as a specific operation.
  • the word "pill” as used herein is merely used for convenience but is defined broadly to include substantially any application method for the subject FCR-FCS operations fluid. However those skilled in the art will recognize that lost circulation problems are frequently treated by "spotting a pill.” Hence the term is used for convenience in reflection to such common application methods, but the methods described and claimed herein include spotting and circulating, without limitation thereto. Consequently, in some embodiments, the step of placing the treatment pill into the wellbore comprises placing the treatment system (operation fluid) into a wellbore that comprises at least one of an NAF mud and an NAF filter cake, such as might occur with use of a hydrocarbon based drilling fluid, emulsion, or invert emulsion, used to drill a wellbore.
  • the step of placing the treatment system into the wellbore comprises placing the water (including any other additives associated with the aqueous phase), the at least one organo-anionic surfactant; the alkyl acid, and the particulate material combined in substantially a common pill mixture.
  • the components of the treatment system are placed into the wellbore in at least two separate steps.
  • the separate steps mya include a remediation step that includes placing a fluid combination comprising the water, the at least one organo-anionic surfactant, and the alkyl acid into the wellbore as a common mixture, and another step includes placing a mixture comprising water and the particulate material into the wellbore.
  • the remediation step may also further comprise introducing the fluid operations fluid combination into at least one of a NAF filter cake and a geologic formation encountered by the wellbore.
  • Still some system aspects may include thereafter placing the mixture comprising water and the particulate material into an area of the wellbore where the fluid combination was placed in the preceding step.
  • the step of placing the treatment pill into the wellbore may comprises placing the treatment pill into a geologic formation and at least partially propping the geologic formation with at least a portion of the particulate material.
  • the particulate material may, for example, be utilized to prop a fracture open long enough to enable leak-off of a fluid into the fracture face and build-up of a sufficiently thick and effective filter cake so as to effectively prevent loss of NAF type fluids from within the fracture or fracture face.
  • placing the treatment pill into the wellbore may comprise placing the treatment pill in contact with an NAF filter cake to cause at least a portion of the fluid phase of the FRC-FCS operations fluid treatment pill to permeate the filter cake.
  • exemplary particulate material may include at least one of sand, clay, diatomaceous earth, organic solids, wellbore cuttings, solid lost circulation materials (LCM), and mixtures thereof.
  • the inventive subject matter includes a method for mitigating loss of wellbore fluid circulation returns, the method comprising: preparing a treatment pill comprising: water (e.g., an aqueous component); at least one organo-anionic surfactant; an alkyl acid; and a particulate material; and placing the treatment pill into a wellbore associated with hydrocarbon production; and disposing the treatment pill on at least one of an open hole section, a natural fracture zone, an operations-created fracture zone, a sand screen components section, a gravel pack components section.
  • water e.g., an aqueous component
  • organo-anionic surfactant e.g., an alkyl acid
  • a particulate material e.g., a particulate material
  • a treatment pill comprises substantially any volume of such FCR-FCS operations fluid treatment as is necessary to effectively treat an application or issue.
  • Exemplary volumes may comprise from one barrel to in excess of 500 barrels, or from one barrel to 500 barrels, or from one barrel to 100 barrels, or from one to fifty barrels, or from one to 20 barrels, or from one to ten barrels.
  • the subject operations fluid may be placed in contact with the relevant section of the wellbore for substantially any necessary amount of time, from a few minutes to substantially continuously.
  • Exemplary contact times may include, for example, up to one-half hour, up to one hour, up to ten hours, up to twenty-four hours, or at least one-half hour, at least one hour, at least two hours, at least one day, for example from at least one-half hour to one week if necessary to enable sufficient time to work a fluid loss or filter cake remediation issue.
  • Other application times may include merely a few minutes, such as up to fifteen minutes, or up to five minutes.
  • the operations fluid treatment pill is substantially continuously circulated across a section of the wellbore.
  • Other aspects of the current invention may also include a method of remediating a NAF filter cake in a well, the method comprising: obtaining an operations fluid comprising an organo-anionic surfactant and an alkyl acid, and water; pumping a volume of the operations fluid into a well including a NAF filter cake, wherein the volume of operations fluid is pumped to contact the NAF filter cake.
  • the method may further comprise thereafter pumping a slurry comprising water and particulate solids into contact with the NAF filter cake.
  • the remediation method may be applied during a drilling operation that is experiencing lost returns, wherein active drilling is paused while the remediation methods and/or operations fluid are applied within the wellbore.
  • the relevant wellbore section may include an open hole segment, wherein the NAF filter cake is formed on a wellbore wall in the open hole segment, and wherein the operations fluid is applied to the open hole segment.
  • the wellbore may be uncased open hole, or may include an un-cemented cased hole segment, wherein the NAF filter cake is formed on a wellbore wall in the un-cemented cased hole segment, and wherein the operations fluid is applied to the un-cemented cased hole segment.
  • the wellbore may also include other completion or casing equipment, such as but not limited to sand control equipment, wherein the NAF filter cake is formed on at least one component of the sand control equipment, and wherein the operations fluid is applied to contact the at least one component of the sand control equipment.
  • the organo- anionic surfactant is selected from the group comprising monoethanol ammonium alkyl aromatic sulfonic acid, monoethanol ammonium alkyl carboxylic acid, and mixtures thereof.
  • the alkyl group of R is an alkyl chain of length at least substantially equal to a hydrocarbon chain length in a non-aqueous fluid in the NAF filter cake.
  • the subject operations fluid may facilitate a method for operating a wellbore, wherein the method comprises: drilling a wellbore through a formation using a NAF-based drilling fluid; and pumping an operations fluid into the wellbore, wherein the operations fluid comprises an organo-anionic surfactant, an alkyl acid, and water.
  • the method of pumping the operations fluid into the wellbore may include maintaining or spotting the operations fluid in substantially non-circulating or substantially static contact with a selected section of the wellbore and allowing the operations fluid to contact and soak or leak off into the selected section of the wellbore for a time interval, such as a selected time interval, such as at least fifteen minutes, or at least thirty minutes, or at least one hour, or at least two hours, or at least 12 hours, or at least 24 hours, or at least 48 hours.
  • a time interval such as at least fifteen minutes, or at least thirty minutes, or at least one hour, or at least two hours, or at least 12 hours, or at least 24 hours, or at least 48 hours.
  • the step of pumping the operations fluid into the wellbore may include circulating the operations fluid across a selected section of the wellbore, such as while circulating the wellbore fluid through a first tubular member and along the wellbore annulus such that the operations fluid contacts the desired section of the wellbore while circulating within the wellbore for a time interval, such as a selected time interval, such as at least fifteen minutes, or at least thirty minutes, or at least one hour, or at least two hours, or at least 12 hours, or at least 24 hours, or at least 48 hours.
  • a time interval such as at least fifteen minutes, or at least thirty minutes, or at least one hour, or at least two hours, or at least 12 hours, or at least 24 hours, or at least 48 hours.
  • Such operation may be conducted during a wellbore operation, such as while performing a drilling operation within the wellbore while substantially simultaneously contacting a selected section of the wellbore with the operations fluid.
  • the method may further comprise thereafter contacting the operations fluid in the wellbore with a mixture of additional water and a solid particulate material.
  • the method may further include the step of pumping at least a portion of the additional water into the formation at the selected section of the wellbore while the additional water is contacting the operations fluid, and may still further comprise pumping the additional water and solid particulate material into a fracture (either natural, inadvertently created, or purposefully created) in the formation at the selected section of the wellbore.
  • An additional step may include a fracture closure stress treatment to the fracture, such as by allowing the stress to be relieved and the fracture to close on the filter cake or on the additional particulate material carried to the filter cake by the operations fluid.
  • the operations fluid may for example, be placed into wellbore subsequent to experiencing loss of wellbore fluid circulation returns.
  • the method may include a further step of thereafter producing hydrocarbons from the well.
  • the blocks, or steps may represent expressions and/or actions to be performed by functionally equivalent circuits or other logic devices.
  • the illustrated blocks may, but are not required to, represent executable instructions that cause a computer, processor, and/or other logic device to respond, to perform an action, to change states, to generate an output or display, and/or to make decisions.
  • the term "and/or" placed between a first entity and a second entity means one of (1 ) the first entity, (2) the second entity, and (3) the first entity and the second entity.
  • Multiple entities listed with “and/or” should be construed in the same manner, i.e., "one or more" of the entities so conjoined.
  • Other entities may optionally be present other than the entities specifically identified by the "and/or” clause, whether related or unrelated to those entities specifically identified.
  • a reference to "A and/or B", when used in conjunction with open-ended language such as “comprising” can refer, in one embodiment, to A only (optionally including entities, other than B); in another embodiment, to B only (optionally including entities other than A); in yet another embodiment, to both A and B (optionally including other entities).
  • These entities may refer to elements, actions, structures, steps, operations, values, and the like.
  • the phrase "at least one,” in reference to a list of one or more entities should be understood to mean at least one entity selected from any one or more of the entity in the list of entities, but not necessarily including at least one of each and every entity specifically listed within the list of entities and not excluding any combinations of entities in the list of entities.
  • This definition also allows that entities may optionally be present other than the entities specifically identified within the list of entities to which the phrase "at least one" refers, whether related or unrelated to those entities specifically identified.
  • At least one of A and B can refer, in one embodiment, to at least one, optionally including more than one, A, with no B present (and optionally including entities other than B); in another embodiment, to at least one, optionally including more than one, B, with no A present (and optionally including entities other than A); in yet another embodiment, to at least one, optionally including more than one, A, and at least one, optionally including more than one, B (and optionally including other entities).
  • each of the expressions “at least one of A, B and C”, “at least one of A, B, or C”, “one or more of A, B, and C", “one or more of A, B, or C” and “A, B, and/or C” may mean A alone, B alone, C alone, A and B together, A and C together, B and C together, A, B and C together, and optionally any of the above in combination with at least one other entity.

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Abstract

L'invention porte sur des fluides, des systèmes et des procédés destinés à être utilisés dans des opérations de forage et de récupération d'hydrocarbures, comprenant de l'eau, au moins un tensioactif organique anionique et un acide alkylique. Les fluides peuvent être utilisés pour traiter un gâteau de filtration de fluide non aqueux (NAF) et/ou pour apporter une solution à un problème de perte dans la circulation de fluide. Les tensioactifs organiques anioniques pour exemple peuvent comprendre un ou plusieurs tensioactifs choisis parmi un sel de monoéthanolammonium d'acide sulfonique aromatique alkylique, un sel de monoéthanolammonium d'acide carboxylique alkylique et les mélanges de ceux-ci. Les acides alkyliques pour exemple comprennent un acide carboxylique alkylique, un acide sulfonique alkylique, un acide carboxylique aromatique alkylique et un acide sulfonique aromatique alkylique.
PCT/US2012/058797 2011-12-12 2012-10-04 Fluides pour des opérations de récupération d'hydrocarbures et leurs procédés d'utilisation Ceased WO2013089896A2 (fr)

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GB2542656A (en) * 2015-07-01 2017-03-29 Calkem (Uk) Ltd Filter cake treatment
US11111426B2 (en) 2018-05-30 2021-09-07 Saudi Arabian Oil Company In-situ salinity adjustment to improve waterflooding performance in oil-wet carbonate reservoirs
US11472994B2 (en) 2018-06-27 2022-10-18 Stepan Company Demulsifying method for drilling fluids

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US5260268A (en) * 1991-07-18 1993-11-09 The Lubrizol Corporation Methods of drilling well boreholes and compositions used therein
US5593954A (en) * 1995-04-26 1997-01-14 The Lubrizol Corporation Friction modifier for water-based well drilling fluids and methods of using the same
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WO2009014585A1 (fr) * 2007-07-26 2009-01-29 Exxonmobil Upstream Research Company Procédé de contrôle de la perte de fluide de forage
US7857055B2 (en) * 2007-12-07 2010-12-28 Schlumberger Technology Corporation High temperature fracturing fluids and method of use
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GB2542656A (en) * 2015-07-01 2017-03-29 Calkem (Uk) Ltd Filter cake treatment
US11111426B2 (en) 2018-05-30 2021-09-07 Saudi Arabian Oil Company In-situ salinity adjustment to improve waterflooding performance in oil-wet carbonate reservoirs
US11472994B2 (en) 2018-06-27 2022-10-18 Stepan Company Demulsifying method for drilling fluids
US11827836B2 (en) 2018-06-27 2023-11-28 Stepan Company Demulsified composition

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