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US20080069961A1 - Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup - Google Patents

Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup Download PDF

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Publication number
US20080069961A1
US20080069961A1 US11/521,105 US52110506A US2008069961A1 US 20080069961 A1 US20080069961 A1 US 20080069961A1 US 52110506 A US52110506 A US 52110506A US 2008069961 A1 US2008069961 A1 US 2008069961A1
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United States
Prior art keywords
reactant
water
polymeric material
carrier fluid
release
Prior art date
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Abandoned
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US11/521,105
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English (en)
Inventor
Diptabhas Sarkar
Stephen T. Arrington
Ronald J. Powell
Ian D. Robb
Bradley L. Todd
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Halliburton Energy Services Inc
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Halliburton Energy Services Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Priority to US11/521,529 priority Critical patent/US20080067108A1/en
Priority to US11/521,105 priority patent/US20080069961A1/en
Priority to US11/521,530 priority patent/US7624743B2/en
Assigned to HALLIBURTON ENERGY SERVICES, INC. reassignment HALLIBURTON ENERGY SERVICES, INC. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: ROBB, IAN D., POWELL, RONALD J., ARRINGTON, STEPHEN T., TODD, BRADLEY L., SARKAR, DIPTABHAS
Priority to CA002628645A priority patent/CA2628645A1/fr
Priority to AU2007297293A priority patent/AU2007297293A1/en
Priority to EP07804260A priority patent/EP2061949A1/fr
Priority to PCT/GB2007/003467 priority patent/WO2008032067A1/fr
Priority to MYPI20081953A priority patent/MY146031A/en
Priority to BRPI0706045-9A priority patent/BRPI0706045A2/pt
Priority to EP11194143.1A priority patent/EP2436872A3/fr
Priority to EP11194138.1A priority patent/EP2436871A3/fr
Priority to RU2008126114/03A priority patent/RU2383716C1/ru
Publication of US20080069961A1 publication Critical patent/US20080069961A1/en
Priority to NO20081875A priority patent/NO341200B1/no
Abandoned legal-status Critical Current

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    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
    • E21B36/008—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones using chemical heat generating means
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J31/00—Catalysts comprising hydrides, coordination complexes or organic compounds
    • B01J31/02—Catalysts comprising hydrides, coordination complexes or organic compounds containing organic compounds or metal hydrides
    • B01J31/04—Catalysts comprising hydrides, coordination complexes or organic compounds containing organic compounds or metal hydrides containing carboxylic acids or their salts
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J31/00—Catalysts comprising hydrides, coordination complexes or organic compounds
    • B01J31/02—Catalysts comprising hydrides, coordination complexes or organic compounds containing organic compounds or metal hydrides
    • B01J31/06—Catalysts comprising hydrides, coordination complexes or organic compounds containing organic compounds or metal hydrides containing polymers
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B08—CLEANING
    • B08B—CLEANING IN GENERAL; PREVENTION OF FOULING IN GENERAL
    • B08B9/00—Cleaning hollow articles by methods or apparatus specially adapted thereto
    • B08B9/02—Cleaning pipes or tubes or systems of pipes or tubes
    • B08B9/027—Cleaning the internal surfaces; Removal of blockages
    • 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
    • C09K8/536—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B37/00—Methods or apparatus for cleaning boreholes or wells
    • E21B37/06—Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting, e.g. eliminating, the deposition of paraffins or like substances
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
    • F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
    • F16L53/00—Heating of pipes or pipe systems; Cooling of pipes or pipe systems
    • F16L53/30—Heating of pipes or pipe systems
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F17D1/16—Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity
    • F17D1/17—Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity by mixing with another liquid, i.e. diluting
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D1/00—Pipe-line systems
    • F17D1/08—Pipe-line systems for liquids or viscous products
    • F17D1/16—Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity
    • F17D1/18—Facilitating the conveyance of liquids or effecting the conveyance of viscous products by modification of their viscosity by heating
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D3/00—Arrangements for supervising or controlling working operations
    • F17D3/16—Arrangements for supervising or controlling working operations for eliminating particles in suspension

Definitions

  • the invention generally relates to the methods for warming a conduit used for hydrocarbon production or transmission to help remediate paraffin wax buildup. More particularly, the invention relates to forming a treatment fluid with reactants that react exothermically to produce heat in a controlled manner and introducing the treatment fluid into the conduit to warm the pipeline. The heat can be used to help remove paraffin wax deposits.
  • Hydrocarbon such as crude oil, for making various grades of fuels and oils, is produced by drilling wells into the earth, either on land or under sea.
  • Crude oil contains many kinds of hydrocarbons, including paraffin wax.
  • Paraffin wax deposition is found practically whenever hydrocarbon (e.g., crude oil) is produced and transported. Paraffin wax deposition obstructs the flow of oil, lowering oil production and interfering with transportation.
  • hydrocarbon e.g., crude oil
  • Paraffin wax deposits are typically made up of linear, saturated hydrocarbon chains (typically C 16 to C 80 ) admixed to branched hydrocarbons, asphaltenes, water, and inorganic compounds such as sand, rust, iron sulfide, clays, etc.
  • the deposit hardness depends chiefly on the oil amounts and mineral substances present in the mixture.
  • the paraffin wax deposition mechanism depends on pressure and temperature. Generally, lower pressures tend to increase the cloud point temperature.
  • the cloud point temperature range of several waxy crude oils is such that the wax can precipitate even on the formation face as well as within the formation throughout the pressure reduction phenomenon which normally occurs during the useful life of the well.
  • the lowering in production rate can be wrongly attributed to the reservoir depletion, while many times it is due to the formation permeability reduction and/or to the reduction of the diameter of the production string.
  • Hydrocarbon chains of different lengths are present in varying percentages as well as melting points, becoming insoluble at different pressure and temperature conditions. Generally, paraffin wax precipitation from hydrocarbon is gradual.
  • Paraffin wax is a dissolved component of relatively hot crude oil.
  • subterranean formations bearing hydrocarbon are usually under high pressure and at temperatures that are higher than 120° F. (49° C.).
  • the formation temperatures of deep formations are usually much higher than 120° F. (49° C.).
  • paraffin wax tends to precipitate from crude oil as waxy solid deposits when the pressure and temperature is lowered as the hydrocarbon is produced and as the crude oil cools down.
  • the hydrocarbon flows from a subterranean formation at relatively high temperature into the production tubulars of the wellbore, it is transported through the tubulars of the wellbore to the wellhead. Further, the hydrocarbon produced at the wellhead must be transported to a refinery to be processed and separated into various components, e.g., to make various grades of fuels and oils. The most common method of transporting hydrocarbon is through pipelines.
  • paraffin wax in the crude oil tends to become a solid, waxy material that falls out of the crude oil and paraffin deposits accumulate on the inner walls of the production tubing and pipelines. This can be particularly problematic in subsea pipelines because the surrounding water on the seafloor is very cold, typically about 39° F. (4° C.).
  • the mechanical approaches are used specially for production strings and pipeline conduits, as they are generally unsuitable for use in a subterranean formation or at the interface between a formation and a wellbore.
  • paraffin deposits are physically removed from the wall surface. Chemical surface agents and solvents can aid in the removal so that the dislodged paraffin deposits are dispersed in solution and can flow through the conduit.
  • the main mechanical approach for helping to clean a pipeline is to run a mechanical device through the pipeline that scrapes the inner wall of the pipeline and pushes the paraffin through.
  • This type of mechanical cleaning device is called a “pig” because the scraping of the inner wall of the pipeline makes a tremendous squealing noise.
  • the pig is normally driven through the pipeline by a relatively high pumping pressure behind the pig, which is used to force the pig through the pipeline. But if paraffin buildup on the inner walls of the pipeline is heavy, as the pig moves forward it will collect so much paraffin in front of the moving pip that it blocks any further movement of the pig.
  • heated oiling The most common thermal method for removing paraffin deposits in production tubulars employs heated oil, so the technique is commonly referred to as “hot oiling.”
  • the heated oil is usually pumped through the annulus between the wellbore and a production tubular, and then back to the surface through the production tubular in order to remove the paraffin wax deposits in the production tubular.
  • This type of approach can be safely used only for production tubulars for paraffin wax deposits above the wellbore perforations to a hydrocarbon-bearing formation. Otherwise, the heated crude oil could carry some of the melted paraffin wax into the formation where it could cool and settle in the porous spaces, plugging the formation.
  • Techniques using heated oil can also be used in pipelines to help remove paraffin wax deposits from the conduit.
  • heated oil is to use heated water.
  • Water has a higher thermal capacity than oil, which capacity can be used to carry more heat energy to melt paraffin wax.
  • the paraffin wax deposits can be thermally dispersed by hot water.
  • hot water does not dissolve or dilute the paraffin wax, so the water and melted paraffin wax can form an undesirable oil/water emulsion.
  • Another disadvantage to using hot water is that it can contribute to corrosion problems with the metal conduits.
  • Organic solvents like hot xylene are able to dissolve paraffins and asphaltenes, but not the inorganic materials in the paraffin wax deposits.
  • the nitrogen-gas-forming mixture can be an aqueous solution of ammonium chloride and sodium nitrite; or an aqueous solution of urea and sodium hypochlorite; or an aqueous solution of urea and sodium nitrite.
  • the fluid contains enough total dissolved solids to provide a solution density exceeding that of the brine in the borehole, such that a significant portion of the heating solution sinks into the column of brine in the borehole and reacts to yield heat and gas that contact the plugged fluid passageways.
  • composition used in the method incorporates an aqueous solution which comprises in-situ nitrogen-generating components together with a sufficient amount of a buffered pH adjuster to produce a buffered pH value for the aqueous solution to abate the time of the reaction rate of the nitrogen-generating components to a level permitting introduction of the components into the isolated length prior to completion of any significant portion of the reaction required to effect temperature melting of the paraffin deposits.
  • a crystalline modifier may be incorporated into the hydrocarbon solution.
  • the nitrogen-generating components comprise sodium nitrite in a concentration ranging from between about 3 to about 10 molar; and ammonium nitrate in a mole concentration approximately equal to that selected for the sodium nitrite.
  • the exothermic reaction employs sodium nitrite and ammonium nitrate in aqueous solution, the reaction products being nitrogen, water and sodium nitrate.
  • the resulting brine is not considered to be deleterious to the formation.
  • the reaction occurs as soon as the forming salts are mixed, in the presence of HCl as catalyst, the control of the reaction being done by buffering the pH of the solution in the range of from 5.0 to 8.0.
  • the reaction is faster at a lower pH. Control is effected such that the reaction begins gradually and progresses slowly as the solution is displaced throughout the production string at constant rate. Nearly 61 meters above the perforations, the reaction rate increases and produces huge amounts of heat, the temperature reaching a thermal maximum, heat being lost to the environment, with consequent reduction in the temperature of the spent solution.
  • the patent more particularly describes a process for the dewaxing of producing formations by means of a water-in-oil nitrogen generating emulsion system, which comprises the steps of: (a) preparing an aqueous solution of NH 4 Cl having a concentration of from 4.0 to 6.0M; (b) preparing an aqueous solution of NaNO 2 having a concentration of from 5.0 to 9.0M; (c) preparing an organic solvent mixture to achieve the hot dissolution of the paraffinic damage; (d) adding an emulsifier to the organic solvents mixture so that the concentration of emulsifier in the mixture comprises between 0.5 to 2.0%; (e) adding acetic acid 96% to the NH 4 Cl solution; (f) adding 50% of the emulsified organic solvents mixture of step (d) to the NH 4 Cl and 50% of the mixture to the NaNO 2 solution obtaining thus a NH 4 Cl emulsion and a NaNO 2 emulsion respectively, both emulsions being kept under agitation
  • the highly exothermic FCR system is demonstrated to be a feasible solution for the billion-dollar problem of paraffin deposition during crude oil production and transportation operations in sub-sea pipelines.
  • Studies of the exothermic reaction in an isothermal reactor showed that hydrogen ions catalyze the reaction by changing the concentration of the reacting species, not by changing the reaction pathways.
  • the rate-limiting step involves the S N 2 reaction between aqueous molecular ammonia and nitrogen trioxide to form nitrosamine.
  • the activation energy of the reaction was found to be about 65.7 kJ/mol experimentally, which compares very favorably (within 11%) with the value found from molecular modeling.
  • the facilitated diffusion of hydrogen ions away from the polymer interface is the principal process that determines the rate limiting step as well as the overall rate of the polymer dissolution.
  • the facilitated diffusion effect increases significantly with an initial increase in the carrier concentration, then approaches a limit at high carrier concentration.
  • there are optimum values of the carrier's pK a and of the solution pH which give a maximum facilitation effect.
  • a homogenous chemico-diffusion model can predict concentration profiles of all species across the diffusion boundary layer and polymer dissolution rates which agree well with experimental results. Good agreement between simulation and experimental results for the FCR system in both batch and flow conditions was achieved. Batch experiments showed that the heat release is controlled by the thickness of the polymeric coating and can be delayed as long as 20 hours.
  • the independent claim is for a method for the thermo-chemical dewaxing of a hydrocarbon transmission conduit containing paraffin deposit, said method comprising the steps of: [sic] (b) maintaining said emulsion in said conduit under conditions sufficient to fluidize the paraffin deposit and to generate nitrogen gas and heat from the reaction of said oxidizing nitrogen salt and said reducing nitrogen salt; and (c) removing the fluidized paraffin deposit from said conduit, wherein the delayed action activator is a linear, aliphatic copolyanhydride solubilized in a polar organic solvent.
  • a method for increasing the temperature of a section of conduit used for the production or transmission of hydrocarbon.
  • the method comprises the step of: forming a treatment fluid comprising: (i) a carrier fluid; and (ii) a first reactant and a second reactant.
  • the first reactant and second reactant are selected for being capable of reacting together in an exothermic chemical reaction; and the first and second reactant are in at least sufficient concentrations in the carrier fluid to generate a theoretical heat of reaction of at least 1,000 kJ/liter of the treatment fluid.
  • At least some of at least one of the first reactant and the second reactant is suspended in the carrier fluid in a solid form that is adapted to help control the release of the reactant into the carrier fluid.
  • the method further comprises the step of: introducing the treatment fluid into a section of conduit used for the production or transmission of hydrocarbon.
  • a method for increasing the temperature of a section of conduit used for the production or transmission of hydrocarbon comprising the steps of: forming a treatment fluid comprising: (i) a carrier fluid; (ii) a first reactant and a second reactant, wherein the first reactant and second reactant are selected for being capable of reacting together in an exothermic chemical reaction; the first and second reactant are in at least sufficient concentrations in the carrier fluid to generate a theoretical heat of reaction of at least 1,000 kJ/liter of the treatment fluid; and (iii) a catalyst for the reaction between the first reactant and the second reactant, wherein at least some of the catalyst is suspended in the carrier fluid in a solid form that is adapted to help control the release of the catalyst into the carrier fluid.
  • the method further comprises the step of: introducing the treatment fluid into a section of conduit used for the production or transmission of hydrocarbon.
  • the treatment fluid After introducing the treatment fluid into the conduit, the treatment fluid is preferably allowed to heat the conduit to help melt the paraffin wax deposits.
  • the treatment fluid preferably includes a liquid hydrocarbon that is a liquid at standard temperature and pressure, which can help dissolve and remove the paraffin wax. The treatment fluid can then be displaced from the section of conduit and help remove the paraffin wax from the section of conduit.
  • a method for controlling the release of at least one reactant of an exothermic reaction into a carrier fluid.
  • the method comprises the steps of: (a) mixing a reactant with a polymeric material, wherein the polymeric material is capable of being hydrated, and water, wherein the proportion of water is insufficient to substantially hydrate the polymeric material but is sufficient to make the polymeric material sticky to help bind the reactant into a matrix; and (b) drying the mixture.
  • the method preferably further comprises the step of: forming the mixture into pellets.
  • a method for controlling the release of a catalyst of an exothermic reaction into a carrier fluid comprising the steps of: (a) mixing the catalyst of an exothermic reaction with a polymeric material, wherein the polymeric material is capable of being hydrated, and water, wherein the proportion of water is insufficient to substantially hydrate the polymeric material but is sufficient to make the polymeric material sticky to help bind the catalyst into a matrix; and (b) drying the mixture.
  • the method preferably further comprises the step of: forming the mixture into pellets.
  • a solid material for controlling the release of a at least one reactant for an exothermic reaction into a carrier fluid comprising the steps of: (a) mixing a reactant with a binding material; and (b) forming the mixture into pellets.
  • a similar method can be used for helping to control the release of a catalyst for an exothermic reaction into a carrier fluid.
  • a solid means and refers to a form of material that is at least initially not dissolved in a fluid.
  • the solid is preferably in the form particulate or small pellets that can be dispersed and suspended in a carrier fluid.
  • the solid can be encapsulated in a solid form.
  • the carrier fluid can have a viscosifier to help suspend the solid form of the reactant or containing the reactant.
  • the solid form of a reactant or comprising a reactant can be, for example, a pure solid, undissolved form of the reactant, a solid matrix of material with the reactant embedded in the matrix, a solid encapsulation of a liquid or solid material with the reactant therein, or any combination in any proportion of any one or more of the foregoing.
  • the solid form is adapted to help control the initial release of the reagent into solution and/or the rate of release of the reagent into solution. This helps control the initiation and/or the rate of reaction between the reactants, respectively, which helps control when the heat of reaction is released.
  • several different examples of techniques are provided for having at least one of the reactants in a solid form, which are adapted to control the mixing of the reactants in a carrier fluid and the generation of the heat of reaction.
  • FIG. 1 is a simplified schematic of an offshore platform for oil production having a pipeline to the shore that is partially blocked by paraffin wax deposits;
  • FIG. 2 is a graphical representation of a guar-bound reactant, which can be generally spherical, other shaped, or an irregular-shaped pellet, and a guar-bound reagent that also has a polyvinyl alcohol coating which dissolves in water at about 120-150° F. (49-65° C.), which can be used together in a carrier fluid to stage the release of one or more reactants;
  • FIG. 3 is a graph showing the control in heat generation that can be achieved where a sample with one of the reactants in a solid form as a guar-bound NaNO 2 matrix that controls the release of nitrite ions over time for reaction with ammonium ions already dissolved in the solution;
  • FIG. 4 is a theoretical graph showing the expected increase in temperature (° F.) over time (hours) for a staged release of solid sodium nitrite into an aqueous solution for the exothermic ammonium chloride and sodium nitrite reaction, where a first line having a single temperature peak at about 1 hour represents the increase in temperature due to the release of the guar-bound reactant, a second dashed line having a single temperature peak at about 3 hours represents the subsequent temperature triggered release of a guar-bound reactant that is coated with polyvinyl alcohol (“PVA”), and a third line having two temperature peaks at about 1 hour and about 3 hours represents the overall temperature of the solution;
  • PVA polyvinyl alcohol
  • FIG. 5 is a graph showing a comparison of guar, xanthan, and carboxymethyl cellulose (“CMC”) as binding materials for controlling the release of one of the reactants in a solid form as a guar-bound, xanthan-bound, or CMC-bound NaNO 2 matrix that controls the release of nitrite ions over time for reaction with ammonium ions already dissolved in the solution;
  • CMC carboxymethyl cellulose
  • FIG. 6 is a graph showing the control in heat generation that can be achieved with one of the reactants in the form of solid, undissolved struvite with a chelating agent to help slowly dissolve the struvite and thereby release ammonium ions for reaction with NaNO 2 already dissolved in the solution;
  • FIG. 7 is a graph showing the control in heat generation that can be achieved where ammonium chloride is first impregnated on diatomaceous earth and subsequently coated with a resin-based slow release agent that controls the release of ammonium ions over time for reaction with nitrite ions already dissolved in the solution; and
  • FIG. 8 is a graph of a delayed exothermic reaction process wherein an exothermic reaction is delayed before it begins by a delayed release acid system but the subsequent reaction is not otherwise controlled.
  • the invention provides for new methods for controlling an exothermic reaction in a treatment fluid, which can be used to facilitate the dissolution and cleanup of paraffin wax buildup in conduits used for hydrocarbon production or transmission.
  • This paraffin deposition leads to reduced crude oil flow and under extreme conditions leads to complete blockage of the pipelines, as previously discussed and as illustrated in FIG. 1 .
  • “Wax” is a low-melting organic mixture or compound of relatively high molecular weight, solid at room temperature and generally similar in composition to fats and oils except that it contains no glycerides. Some are hydrocarbons; others are esters of fatty acids and alcohols. They are classed among the lipids. Waxes are thermoplastic, but since they are not high polymers, are not considered in the family of plastics. Common properties are water repellency, smooth texture, low toxicity, freedom from objectionable odor and color. They are combustible and have good dielectric properties; soluble in most organic solvents; insoluble in water. A major type of wax is paraffin wax. Hawley's Condensed Chemical Dictionary, 14 th Edition, Ed. Richard J. Lewis, 2001, p. 1174.
  • Paraffin in a broad sense, is also known as alkane, a class of aliphatic hydrocarbons characterized by a straight or branched carbon chain; generic formula C n H 2n+2 . Their physical form varies with increasing molecular weight from gases (methane) to waxy solids. In a narrower sense, “paraffin” refers to paraffin wax. Hawley's Condensed Chemical Dictionary, 14 th Edition, Ed. Richard J. Lewis, 2001, p. 835.
  • Paraffin wax has the properties of being a white, translucent solid; tasteless; odorless; combustible; consisting of a mixture of solid hydrocarbons of high molecular weight, e.g., C 36 H 74 .
  • Paraffin wax has density of 0.880-0.915, melting point 116-149° F. (47-65° C.), flash point 390° F. (198° C.), auto-ignition temperature 473° F. (245° C.).
  • Paraffin wax is soluble in benzene, ligroin, warm alcohol, chloroform, turpentine, carbon disulfide, and olive oil; insoluble in water and acids. Hawley's Condensed Chemical Dictionary, 14 th Edition, Ed. Richard J. Lewis, 2001, p. 835.
  • solubility of a substance is its concentration in a saturated solution.
  • a substance having a solubility of less than 1 g/100 mL of solvent is usually considered insoluble.
  • the solubility is sometimes called “equilibrium solubility” because the rates at which solute dissolves and is deposited out of solution are equal at this concentration.
  • first and second are arbitrarily assigned and are merely intended to differentiate between two or more reactants. It is to be understood that the words “first” and “second” serve no other purpose and are not part of the name or description of the reactant. Furthermore, it is to be understood that that the mere use of the term “first” and “second” does not require that there be any “third” or further reactant, although that possibility is contemplated under the scope of the present invention.
  • the process will: (a) be delayed in starting to produce heat until after a sufficient time to deliver the treatment fluid to a section of a conduit to be treated, which may have paraffin buildup or be substantially blocked by paraffin; and (b) heat the section of conduit for at least about 2 hours and preferably for about 3-5 hours, thereby having enough time to impart the heat to the paraffin and cause it to at least soften, and preferably melt.
  • the preferred exothermic reaction is an acid catalyzed reaction between ammonium chloride and sodium nitrite, as shown in the following reaction (Equation 1):
  • ammonium chloride and sodium nitrite are the presently most preferred reactants.
  • the objective is to have at least one of the reactants in a solid form to help control this exothermic reaction so that the heat of reaction energy is released over a period of time instead of as an energy spike. It should be noted that the control of the mixing of the reactants is not expected to substantially affect the total amount of heat that is generated. There are several examples of different types of solid materials that can be employed.
  • At least one of the reactants can be embedded in a solid matrix comprising a material that helps delay the release of the reactant.
  • the slow release of a reactant can provide a controlled reaction for heat generation.
  • At least one of the reactants can be encapsulated with an encapsulating material to form a solid capsule for the reactant.
  • the slow release of a reactant can provide a controlled reaction for heat generation
  • FIG. 2 is a graphical representation of a guar-bound reactant, which can be generally spherical, other shaped, or an irregular-shaped pellet, and a similar guar-bound material that also has a polyvinyl alcohol coating which dissolves in water at about 120-150° F. (49-65° C.), which can be used together in a carrier fluid to stage the release of one or more reactants.
  • a solid guar-bound reactant can be formed, for example, by mixing about 95% by weight of a reactant, 4% by weight dried guar gum powder, and about 1% by weight water.
  • the substantially pure reactant is naturally in a solid form at standard temperature and pressure, e.g., sodium nitrite.
  • Guar is a polymeric material that can be hydrated. The amount of water is insufficient to substantially hydrate the guar powder, but is sufficient to make the polymeric material sticky to help bind the reactant into a matrix.
  • the materials can be mixed together into a solid matrix, which can then be formed into small pellets. These pellets are subsequently dried in a vacuum oven at about 80° C. for about 12 hours to substantially reduce the moisture content and obtain the final product.
  • the guar-bound dry matrix also acts as a vehicle for a slow release of the reactant salt into solution.
  • the size of these pellets can be varied as desired. Preferably, the pellets vary in size from about 1 to about 10 mm across.
  • some or all of the solid guar-bound reactant can optionally be coated or encapsulated with a material to delay the release of at least some of a guar-bound reactant, which can be used to help stage or incrementally mix the reactants to control the release of the heat of reaction.
  • pellets of a material comprising a solid reactant, by itself or in a solid matrix can be encapsulated to control the release of the reactant.
  • the encapsulating material can be slowly dissolvable in one of the components of the carrier fluid, or sensitive to a change in pH of an aqueous environment, or sensitive to an increase in temperature.
  • chitosan can be used as a coating or encapsulating material. Chitosan dissolves in acetic acid which is a catalyst for the reaction. The chitosan coated material can be suspended in a viscosified acetic acid solution. The time taken by the chitosan to dissolve in an acetic acid solution would achieve delay in initiating the reaction.
  • examples include polyvinyl alcohol or hydrogenated vegetable oil.
  • Any of one or more of these various techniques can be used, separately or together, to help control the release of a reactant.
  • FIG. 3 is a graph showing the control in heat generation that can be achieved where a sample with one of the reactants in a solid form as a guar-bound NaNO 2 matrix that controls the release of nitrite ions over time for reaction with ammonium ions already dissolved in the solution.
  • a first line shows the change in temperature over time for an uncontrolled or fast reaction of aqueous solution phase reactions of 5M NH 4 Cl with 5M NaNO 2 in the presence of acetic acid.
  • a second line shows the change in temperature over time for a controlled or slow reaction of an aqueous solution of NH 4 Cl with guar-bound NaNO 2 in the presence of acetic acid.
  • FIG. 4 is a conceptual graph showing an expected combined temperature profile (° F.) over time (hours) for a staged release of solid sodium nitrite into an aqueous solution for the exothermic ammonium chloride and sodium nitrite reaction, where a first line represents the increase in temperature due to the release of the guar-bound reactant, a second line represents the subsequent temperature triggered release of a guar-bound reactant that is coated with polyvinyl alcohol (“PVA”), and a third line represents the overall temperature of the solution.
  • PVA polyvinyl alcohol
  • FIG. 5 is a graph showing a comparison of guar, xanthan, and carboxymethyl cellulose (“CMC”) as binding materials for controlling the release of one of the reactants in a solid form as a guar-bound, xanthan-bound, or CMC-bound NaNO 2 matrix that controls the release of nitrite ions over time for reaction with ammonium ions already dissolved in the solution.
  • CMC carboxymethyl cellulose
  • the guar appears to provide the slowest release of the three tested materials with an incomplete release, i.e., residual lumps at the end of the test period.
  • the xanthan as binder material provided a more complete release of the solid form NaNO 2 into an aqueous solution for reaction with the dissolved NH 4 Cl in the presence of acetic acid.
  • the CMC as a binder material delayed the release of the solid form NaNO 2 into an aqueous solution but did not greatly control or slow the release.
  • binder materials or a combination of two or more of such materials, is expected to be useful for helping to control the release of a solid form reactant into an aqueous solution for the purposes of the present invention.
  • Guar is presently the most preferred binder material.
  • undissolved solid struvite is used in place of ammonium chloride in the reaction shown above in Equation 1.
  • Struvite is a magnesium ammonium phosphate and acts as a source of ammonium ions.
  • Magnesium ammonium phosphate (MgNH 4 PO 4 *6H 2 O) is a white powder, density 1.71, melting point (decomposes to magnesium pyrophosphate, Mg 2 P 2 O 7 ), soluble in acids, insoluble in alcohol and water.
  • struvite As struvite is known to be insoluble in water, however, but soluble in acidic solutions and the dissolution of struvite is also known to be enhanced by the presence chelating agents (e.g., citric acid, sodium salts of ethylenediamine tetraacetic acid (“EDTA”)), which bind onto magnesium thereby breaking the solid matrix.
  • chelating agents e.g., citric acid, sodium salts of ethylenediamine tetraacetic acid (“EDTA”)
  • EDTA ethylenediamine tetraacetic acid
  • FIG. 6 is a graph showing the control in heat generation that can be achieved with one of the reactants in the form of solid, undissolved struvite and a chelating agent to slowly dissolve the struvite and thereby release ammonium ions for reaction with NaNO 2 already dissolved in the solution.
  • the NH 4 Cl is bound into a solid form. More particularly, in this embodiment the NH 4 Cl is impregnated on diatomaceous earth and subsequently coated with a resin-based slow release agent. The particle size was 20-40 mesh.
  • FIG. 7 is a graph showing the control in the release of ammonium ions over time for reaction with nitrite ions already dissolved in a test solution in the presence of acetic acid, which helps control the timing and rate of heat generation. In FIG.
  • a first line plotted on the graph shows the change in temperature over time for an uncontrolled or fast reaction of aqueous solution phase reactions of 5M NH 4 Cl with 5M NaNO 2 in the presence of acetic acid reaching a maximum temperature of about 190° F.
  • a second line shows the change in temperature over time for a controlled or slow reaction of a 32% by weight encapsulation of NH 4 Cl with aqueous dissolved NaNO 2 in the presence of acetic acid reaching a maximum temperature of about 140° F.
  • a third line shows the change in temperature with a 36% by weight encapsulation of NH 4 Cl reaching a maximum temperature of about 100° F.
  • a fourth line shows the change in temperature with a 44% by weight encapsulation of NH 4 Cl reaching a maximum temperature of about 80° F.
  • FIG. 8 is a graph of a delayed exothermic reaction process wherein an exothermic reaction is delayed before it begins by a delayed release acid system.
  • a technique that can be used to delay the reaction includes using a neutral or alkaline solution and delaying the release of an acid.
  • Another example of a technique for delaying the start of includes encapsulating one or both of the reagents for an exothermic reaction to delay the initial release of the reagent or reagents.
  • the exothermic reaction according to Eq. 1 also produces nitrogen gas.
  • the generated nitrogen gas can produce a foamed fluid. It is believed that the foamed fluid can help provide a margin for safety in controlling the release of pressure generated by the nitrogen gas.
  • a non-ionic surfactant in the treatment fluid would be made to go past its cloud point due to the generation of heat. Above the cloud point, a surfactant would tend to penetrate the paraffin deposits. When the temperature comes down to ambient conditions, the surfactant would want to go back to solution, thereby pulling the paraffin molecules with them. Thus, this detergent like effect due to the heating with a non-ionic surfactant is expected to add considerable synergy to the paraffin wax removal methods.
  • the choice of surfactants would vary on a case to case basis. The right surfactant would be expected to have a cloud point at least 10-15 degrees above the ambient temperature.
  • a method for increasing the temperature of a section of conduit used for the production or transmission of hydrocarbon comprising the steps of: (a) forming a treatment fluid comprising: a carrier fluid; and a first reactant and a second reactant, wherein: the first reactant and second reactant are selected for being capable of reacting together in an exothermic chemical reaction; the first and second reactant are in at least sufficient concentrations in the carrier fluid to generate a theoretical heat of reaction of at least 1,000 kJ/liter of the treatment fluid; and at least some of at least one of the first reactant and the second reactant is suspended in a solid form in the carrier fluid; and (b) introducing the treatment fluid into a section of conduit used for the production or transmission of hydrocarbon.
  • the reactants and concentrations are selected to generate a theoretical heat of reaction of at least 1,500 kJ/of the treatment fluid.
  • the solid form is further adapted to help control the mixing between the first reactant and the second reactant. More preferably, the solid form is adapted to help control the mixing so that: (a) less than 50% of the total heat of the reaction is generated within any 1 hour period; and (b) greater than 50% of the total heat of the reaction is generated within a period of at most 6 hours.
  • the purpose is to have the heat of reaction releases, whether at an even rate or in stages, so that a major spike in the release of heat energy is avoided, but that substantially all of the heat energy is released within a matter of hours. Most preferably, the heat of reaction is released over a period of about 3 to about 5 hours.
  • the solid form can comprise at least two different solid forms adapted to help control the mixing between the first reactant and the second reactant in at least two stages.
  • the solid form preferably substantially comprises particulate material. More preferably, the solid material is of a 20-40 mesh size.
  • the carrier fluid preferably comprises a viscosifying agent.
  • the viscosifying agent helps suspend solid material in the carrier fluid.
  • the viscosifying agent can comprise: a water-soluble polymeric material. More preferably, the viscosifying agent may be a polysaccharide selected from the group consisting of: guar, hydroxylalkylguar, carboxyalkylhydroxyalkylguar, carboxyalkylcellulose, carboxyalkylhydroxyalkyl-cellulose, xanthan, derivatives of any of the foregoing, and any combination thereof in any proportion.
  • the viscosifying agent can further comprise a crosslinking agent.
  • the treatment fluid can further comprise a breaker for the viscosifying agent.
  • the carrier fluid preferably comprises water.
  • the water can be selected from the group consisting of: seawater; brackish water; freshwater; and any combination thereof in any proportion.
  • the carrier fluid preferably comprises a hydrocarbon that is a liquid at standard temperature and pressure (“STP”), which can help dissolve paraffin wax.
  • STP standard temperature and pressure
  • the carrier fluid is an emulsion of water and hydrocarbon.
  • the hydrocarbon in the carrier fluid is selected from the group consisting of: crude oil, kerosene, an aromatic solvent, and any combination thereof in any proportion. These are selected for their ability to dissolve paraffin wax.
  • the treatment fluid further comprises a crystalline modifier to help dissolve the paraffin wax.
  • the crystalline modifier can help dissolve or break up the deposited paraffin wax and it can help prevent dissolved or melted paraffin wax from redepositing elsewhere.
  • the first reactant and the second reactant, and any catalyst are preferably further selected for not having any detrimental effect on the pipeline.
  • first reactant and the second reactant are also preferably selected for having a relatively low activation energy of reaction.
  • the treatment fluid is preferably formulated such that it does not set or solidify, whereby the treatment fluid cannot itself inadvertently plug the conduit.
  • At least one of the first reactant and the second reactant preferably is a water-soluble material. More preferably, both the first reactant and the second reactant each comprise a water-soluble material.
  • the first reactant comprises: a source of cations
  • the second reactant comprises a source of anions.
  • the source of cations comprises: a source of ammonium ions
  • the source of anions comprises: a source of nitrite ions.
  • the source of ammonium ions preferably comprises an ammonium halide, and most preferably the ammonium halide comprises an ammonium chloride.
  • Ammonium Sulfate and Ammonium Nitrate could also be used. But Ammonium Nitrate is less preferable because of its explosive nature.
  • the source of nitrite ions comprises: an alkali nitrite, and most preferably, the source of nitrite ions comprises: sodium nitrite.
  • the reaction may be assisted by or require a catalyst for an exothermic chemical reaction between the first reactant and the second reactant.
  • the step of forming a treatment fluid preferably further comprises: forming a treatment fluid further comprising a catalyst for an exothermic chemical reaction between the first reactant and the second reactant.
  • the release of the catalyst may occur after some of one of the reactants has been released from its solid form to become available for reaction, such that a small initial spike in heat energy is allowed followed by a more sustained or stepped release of heat energy depending on the nature of the solid form of one or both of the reactants.
  • the encapsulating or embedding material for delaying the release of acid can be any material that melts or dissolve in the carrier fluid upon reaching a certain temperature to release the acid. Further, the dissolution of the polymeric material would be expected to increase with increasing temperature.
  • the polymeric material can be a material that releases the encapsulated reactant upon reaching or exceeding a specific temperature.
  • the polymeric material can be selected to release a reactant at or above a temperature of 120° F. (49° C.), for example, polyvinyl alcohol.
  • a polymeric material can be selected that releases the encapsulated reactant at a temperature above 150° F. (65° C.).
  • encapsulating materials that have low melting points in these ranges also include vegetable oil based encapsulating materials, such as those described in U.S. Pat. No. 6,153,236 issued Nov. 28, 2000 to Balchem Corporation.
  • the catalyst is preferably an acid, and more preferably a carboxylic acid.
  • the acid is selected from the group comprising: acetic acid, citric acid, lactic acid, and any combination thereof in any proportion.
  • the acid should be effective to make the pH of the water in the carrier fluid less than or equal to about 5.5.
  • the method preferably further comprises the step of: delaying the release of the acid to help delay the beginning of any substantial reaction between the first reactant and the second reactant.
  • the step of delaying the release of the acid can comprise: including a delayed release acid in the treatment fluid.
  • the specific solid form of a reactant can be used to control the mixing of the reactants, either the timing of the mixing in stages of release or the rate of a steady release of at least one of the reactants for a controlled steady rate of mixing and reaction, or any combination of such objectives.
  • the solid form for a reactant comprises: having at least some of at least one of the first reactant and the second reactant is embedded in a solid matrix with a polymeric material.
  • the solid form comprises for a reactant comprises: having at least some of at least one of the first reactant and the second reactant is encapsulated with a polymeric material capable of helping to control the release of the reactant.
  • the embedding material is preferably a polymeric material. More particularly, the polymeric material preferably comprises a biopolymeric material or a derivative of a biopolymeric material. More preferably, the biopolymeric material is selected from the group consisted of hydroxyl alkyl cellulose, xanthan, diutan, guar gum, chitosan, in any combination and in any proportion.
  • the polymeric material is a material that can be hydrated.
  • a small proportion of water is added, which preferably is an insufficient proportion to substantially hydrate the polymeric material, but is sufficient to make the polymeric material sticky to help bind the reactant into a matrix.
  • the materials can be mixed together into a solid matrix, which can then be formed into small pellets. These pellets are subsequently dried, for example, in a vacuum oven at about 80° C. for about 12 hours to obtain the final product.
  • the polymer-bound dry matrix also acts as a vehicle for a slow release of the reactant salt into solution.
  • the size of these pellets can be varied as desired. Preferably, the pellets vary in size from about 1 to about 10 mm across. If desired, the uniformity of pellet size can be controlled by screening techniques.
  • the encapsulating or embedding material preferably comprises a water-soluble polymeric material. More preferably, for example, the water-soluble the polymeric material is selected from the group consisting of polyvinyl alcohols, polyvinyl alcohol copolymers, partially hydrolyzed polyvinyl acetate, polyvinyl pyrrolidone, alkyl celluloses, ethers and esters of alkyl cellulosics, hydroxy alkyl, carboxy methyl cellulose sodium, dextrin, maltodextrin, water soluble polyacrylates, water soluble polyacrylamides, acrylic acid/maleic anhydride copolymers, and any combination thereof in any proportion. Based on the teachings of this invention, a person of skill in the art will be able to select particularly appropriate polymeric materials and an appropriate physical solid form to achieve a release of reactant after a desired time or after a desired temperature.
  • the encapsulating or embedding material can be sensitive to temperature.
  • polyvinyl alcohol or hydrogenated vegetable oil can be used.
  • the encapsulating or embedding material can be any material that melts or dissolve in the carrier fluid to release a reactant for an exothermic reaction. Further, the dissolution of the polymeric material would be expected to increase with increasing temperature.
  • one portion of one of the reactants is encapsulated in a first polymeric material that releases the reactant at a lower temperature and another portion of the reactant is encapsulated in a second polymeric material that releases the reactant at a higher temperature, it is possible to control the mixing of the reactants in stages. This principle can be extended to release successive portions of a reactant as the temperature of the treatment fluid increases with each successive release of reactants to generate some of the available heat of reaction for all the reactant material in the carrier fluid.
  • the polymeric material can be selected to dissolve in an acidic solution, wherein the carrier fluid comprises water at a neutral or alkaline pH; and wherein the treatment fluid further comprises a delayed release acid.
  • the pH of the water in the carrier fluid would become acidic, which can be used to begin to release some of one of the reactants into the carrier fluid.
  • a polymeric material is chitosan, alone or in combination with sodium alginate, which material would dissolve in an acetic acid solution.
  • Other examples include synthetic, cationic polymers.
  • the solid form comprises: having at least some of at least one of the first reactant and the second reactant in a solid form that is insoluble in neutral water; and wherein the treatment fluid comprises: an agent to increase the solubility of such reactant in water.
  • the first reactant comprises: magnesium ammonium phosphate in solid form that is soluble in water at a very slow rate of dissolution
  • the second reactant comprises a source of nitrite ions
  • the agent to increase the rate of dissolution of the magnesium ammonium phosphate comprises a chelating agent.
  • the chelating agent is preferably selected from the group consisting of: citric acid, alkali salts of ethylenediaminetetraacetic acid (“EDTA”), nitrilotriacetic acid (“NTA”), and any combination thereof in any proportion.
  • EDTA ethylenediaminetetraacetic acid
  • NTA nitrilotriacetic acid
  • the methods can also preferably further comprise the step of: isolating the section of conduit; and wherein the step of introducing the treatment fluid into the conduit further comprises: introducing into the isolated section of conduit.
  • the method according to the invention can further preferably comprising the step of: allowing the treatment fluid to generate heat in the conduit. This is important to allow the paraffin wax deposits time to heat up and begin to soften or melt.
  • the carrier fluid comprises liquid hydrocarbon that can dissolve the paraffin wax to help remove the deposits.
  • the methods further comprise the step of: displacing the treatment fluid from the section of conduit.
  • a non-ionic surfactant is added to the treatment fluid, which in addition to providing a detergency effect, can also help to emulsify organic solvents that will aid in dissolving the wax deposits.
  • the treatment fluid can also have pour point depressants (to modify the structure of the deposited wax) provided antagonistic effects are not observed with the non-ionic surfactants.
  • the Fenton's Reaction has been known since 1894 and is one of the most powerful oxidizing reactions available.
  • the Fenton's Reaction is of interest because it is highly exothermic.
  • the Fenton's Reaction involves hydrogen peroxide and a ferrous iron catalyst (Equation 2).
  • the peroxide is broken down into a hydroxide ion and a hydroxyl free radical.
  • the hydroxyl free radical is the primary oxidizing species and can be used to oxidize and break apart organic molecules.
  • Fenton's Reaction can be used to oxidize hydrocarbon as one of the reactants to generate heat included in the carrier fluid. Even if not particularly reactive with paraffin wax already in the conduit to be treated, the heat generated by Fenton's Reaction with the hydrocarbon in the carrier fluid can be used to melt and help dissolve the paraffin wax. The heat of this reaction would be expected to be limited by the amount of hydrogen peroxide and ferrous iron used in the treatment fluid, and an excess of hydrocarbon would be used for dissolving the paraffin wax in the conduit.
  • Grignard reactions Another highly exothermic class of reactions is Grignard reactions, for which the heat of reaction is typically in the range of about ⁇ 200 to about ⁇ 250 kJ/mole.

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US11/521,529 US20080067108A1 (en) 2006-09-14 2006-09-14 Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup
US11/521,105 US20080069961A1 (en) 2006-09-14 2006-09-14 Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup
US11/521,530 US7624743B2 (en) 2006-09-14 2006-09-14 Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup
RU2008126114/03A RU2383716C1 (ru) 2006-09-14 2007-09-13 Способы и составы для тепловой обработки трубопровода, используемого для добычи или транспортировки углеводорода, для облегчения удаления отложений твердых парафинов
PCT/GB2007/003467 WO2008032067A1 (fr) 2006-09-14 2007-09-13 Procédés et composition de traitement thermique d'un conduit de production ou transfert d'hydrocarbure pour faciliter l'élimination des accumulations de cire de paraffine
AU2007297293A AU2007297293A1 (en) 2006-09-14 2007-09-13 Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup
EP07804260A EP2061949A1 (fr) 2006-09-14 2007-09-13 Procédés et composition de traitement thermique d'un conduit de production ou transfert d'hydrocarbure pour faciliter l'élimination des accumulations de cire de paraffine
CA002628645A CA2628645A1 (fr) 2006-09-14 2007-09-13 Procedes et composition de traitement thermique d'un conduit de production ou transfert d'hydrocarbure pour faciliter l'elimination des accumulations de cire de paraffine
MYPI20081953A MY146031A (en) 2006-09-14 2007-09-13 Methods and compositions for thermally treating a conduit used for hydrocarbon production or transmission to help remove paraffin wax buildup
BRPI0706045-9A BRPI0706045A2 (pt) 2006-09-14 2007-09-13 método para aumentar a temperatura de um seção do conduto utilizada para a produção ou transmissão de hidrocarbonetos, método para o controle da liberação de pelo menos um reagente e de um catalisador, produto, e, métodos para a produção de um material sólido para o controle da liberação pelo menos de um reagente e de pelo menos de um catalisador
EP11194143.1A EP2436872A3 (fr) 2006-09-14 2007-09-13 Procédés et compositions pour le traitement thermique d'une conduite utilisée pour la production d'hydrocarbures ou la transmission pour faciliter l'élimination de l'accumulation de cire de paraffine
EP11194138.1A EP2436871A3 (fr) 2006-09-14 2007-09-13 Procédés et compositions pour le traitement thermique d'une conduite utilisée pour la production d'hydrocarbures ou la transmission pour faciliter l'élimination de l'accumulation de cire de paraffine
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US20080066784A1 (en) 2008-03-20
CA2628645A1 (fr) 2008-03-20
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US20080067108A1 (en) 2008-03-20
EP2436872A3 (fr) 2016-11-30
EP2436872A2 (fr) 2012-04-04
EP2061949A1 (fr) 2009-05-27
US7624743B2 (en) 2009-12-01
MY146031A (en) 2012-06-15
NO341200B1 (no) 2017-09-11
EP2436871A2 (fr) 2012-04-04
RU2383716C1 (ru) 2010-03-10
BRPI0706045A2 (pt) 2011-03-22
EP2436871A3 (fr) 2016-12-28
WO2008032067A1 (fr) 2008-03-20
RU2008126114A (ru) 2010-01-10

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