High molecular weight inhibitors for downhole operations

Abstract

An inhibitor composition includes a hyperbranched polymer in an amount of 1 to 50 weight percentage of total weight of the inhibitor composition. The hyperbranched polymer comprises a main anchoring group with functionalized pendant chains with at least two polar functional groups. The inhibitor composition also includes at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.

Description

IS25.0295 (SCFT:0420)HIGH MOLECULAR WEIGHT INHIBITORS FOR DOWNHOLE OPERATIONSCROSS-REFERENCE TO RELATED APPLICATIONS

[0001] This application is claims benefit of U.S. Provisional Patent Application No. 63 / 688,341, filed on August 29, 2024, and U.S. Provisional Patent Application No. 63 / 720,490, filed on November 14, 2024, which are hereby incorporated by reference in their entirety for all purposes.BACKGROUND

[0002] The present disclosure generally relates to techniques to inhibit agglomeration or precipitation of high molecular weight components. More specifically, the present disclosure relates to an inhibitor composition that includes at least a hyperbranched polymer and methods and systems for utilizing the inhibitor composition.

[0003] This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and / or claimed below. This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure. Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.

[0004] Under reservoir conditions, asphaltenes are organic heterocyclic macromolecules, where paraffins are aliphatic (e.g., linear, branched, or cyclic) hydrocarbons, that may be stabilized by maltenes and resin acids. Agglomerations of asphaltene and / or paraffins can increase the viscosity of crude oil and cause blockages in pipelines as they grow. Moreover, asphaltene and / or paraffins aggregates can precipitate from crude oil and deposit in reservoirs, wellbore tubing, flowlines, separators, and other components of hydrocarbon production systems, potentially causing formation damage and production declines, which are both costly for the oil industry.IS25.0295 (SCFT:0420)

[0005] Besides mechanical methods, aromatic solvents can be added to high molecular weight components (e g., asphaltenes) to dissolve them. Although asphaltene or certain other high molecular weight components (e.g., paraffin) is very soluble in aromatic solvents, improper cleaning can lead to slow re-precipitation. To solve these problems, inhibitors and dispersants may be added to the production process.SUMMARY

[0006] A summary of certain embodiments disclosed herein is set forth below. It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure. Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.

[0007] In certain embodiments, the present disclosure relates to an inhibitor composition. The inhibitor composition includes a hyperbranched polymer in an amount of 1 to 50 weight percentage of total weight of the inhibitor composition. The hyperbranched polymer includes a main anchoring group with functionalized pendant chains with at least two polar functional groups. The inhibitor composition also includes at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.

[0008] In certain embodiments, the present disclosure relates to a method. The method includes obtaining an inhibitor composition. The inhibitor composition includes a hyperbranched polymer in an amount of 1 to 50 weight percentage of total weight of the inhibitor composition. The hyperbranched polymer includes a main anchoring group with functionalized pendant chains with at least two polar functional groups. The inhibitor composition also includes at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.

[0009] In certain embodiments, the present disclosure relates to a system. The system includes a vessel disposed in a subterranean environment. The vessel includes an inhibitor composition. The inhibitor composition includes a hyperbranched polymer in an amount ofIS25.0295 (SCFT:0420)1 to 50 weight percentage of total weight of the inhibitor composition. The hyperbranched polymer includes a main anchoring group with functionalized pendant chains with at least two polar functional groups. The inhibitor composition also includes at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.

[0010] The brief summary presented above is intended only to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.BRIEF DESCRIPTION OF THE DRAWINGS

[0011] These and other features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein:

[0012] FIG. l is a block diagram of a process for producing an inhibitor composition, in accordance with an embodiment of the present disclosure; and

[0013] FIG. 2 is a system for injecting or providing the inhibitor composition of FIG. 1.DETAILED DESCRIPTION

[0014] Certain embodiments commensurate in scope with the present disclosure are summarized below. These embodiments are not intended to limit the scope of the disclosure, but rather these embodiments are intended only to provide a brief summary of certain disclosed embodiments. Indeed, the present disclosure may encompass a variety of forms that may be similar to or different from the embodiments set forth below.

[0015] As used herein, the term “coupled” or “coupled to” may indicate establishing either a direct or indirect connection (e.g., where the connection may not include or include intermediate or intervening components between those coupled), and is not limited to either unless expressly referenced as such. The term “set” may refer to one or more items.IS25.0295 (SCFT:0420)Wherever possible, like or identical reference numerals are used in the figures to identify common or the same elements. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale for purposes of clarification.

[0016] As used herein, the terms “inner” and “outer”; “up” and “down”; “upper” and “lower”; “upward” and “downward”; “above” and “below”; “inward” and “outward”; and other like terms as used herein refer to relative positions to one another and are not intended to denote a particular direction or spatial orientation. The terms “couple,” “coupled,” “connect,” “connection,” “connected,” “in connection with,” and “connecting” refer to “in direct connection with” or “in connection with via one or more intermediate elements or members.”

[0017] Furthermore, when introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements. The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements. Additionally, it should be understood that references to “one embodiment,” “an embodiment,” or “some embodiments” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features. Furthermore, the phrase A “based on” B is intended to mean that A is at least partially based on B. Moreover, unless expressly stated otherwise, the term “or” is intended to be inclusive (e.g., logical OR) and not exclusive (e.g., logical XOR). In other words, the phrase A “or” B is intended to mean A, B, or both A and B.

[0018] As used herein, a component that is “positioned along”, “positioned upstream”, and “positioned downstream” with respect to a flow path, indicates that the component receives a fluid along the flow path and / or provides, generate, or otherwise modifies a fluid along the flow path.

[0019] As used herein, an “inhibitor” refers to a chemical component that substantially reduces or prevents agglomeration and / or precipitation of high molecular weightIS25.0295 (SCFT:0420) components. At least in some instances, inhibitors may also provide beneficial effects associated with a “viscosity reducer”, a “pour point depressant”, a “flow improver”, a “dispersant”, or a combination thereof.

[0020] The terms “formation” or “subterranean formation” as utilized herein should be understood broadly, and are used interchangeably. A formation includes any underground fluidly porous formation, and can include without limitation any oil, gas, condensate, mixed hydrocarbons, paraffin, kerogen, water, and / or CO2 accepting or providing formations. A formation can be fluidly coupled to a wellbore, which may be an injector well, a producer well, and / or a fluid storage well. The wellbore may penetrate the formation vertically, horizontally, in a deviated orientation, or combinations of these. The formation may include any geology, including at least a sandstone, limestone, dolomite, shale, tar sand, and / or unconsolidated formation. The wellbore may be an individual wellbore and / or a part of a set of wellbores directionally deviated from a number of close proximity surface wellbores (e.g. off a pad or rig) or single initiating wellbore that divides into multiple wellbores below the surface.

[0021] As discussed above, certain high molecular weight components (e.g., asphaltenes, paraffin, waxes, and other high molecular weight hydrocarbon materials) may precipitate or agglomerate due to subterranean conditions. For example, in subsea operations, relatively low temperatures and high pressures may cause the high molecular weight components to agglomerate as the fluid is pumped from a reservoir. Fluids produced from the reservoir invariably cool and undergo pressure and temperature changes. This causes the high molecular weight components to precipitate out as solids. For example, paraffins may crystallize out of the crude oil. Waxes (e.g., paraffins) are saturated, nonpolar hydrocarbons with chain lengths of C15 to C80 and above. The waxy solids cause potential problems in the production and transportation process. When waxes condense on cooled surfaces, such as pipe walls and teller lines, fluid flow is blocked. Another major issue especially for subsea flowlines, is the build-up of solids waxy layers on the pipe walls. As a result of wax solidification in storage tanks, sludge formation is a common issue for crude oil shipping. The agglomerations and / or precipitation may result in unexpected or undesirable operationsIS25.0295 (SCFT:0420)(e.g., that may result in shutdown or delays) of hydrocarbon extraction components, such as damaging equipment, clogging equipment, or otherwise preventing the equipment from operating in a desired and / or efficient manner.

[0022] Conventional solutions to prevent precipitation or agglomeration on the surface is to insulate the lines and add heat. The cost of insulating lines is high and not always justified. Downhole waxing problems cannot be addressed by this technique. Hot oiling is one example of a conventional downhole treatment. In this process, crude oil is heated to a temperature above wax crystallization and circulated through pipelines where wax builds up. Hot oiling may utilize a large heat source, which is not desirable on every production line. Further, hot oiling may not completely de-wax the equipment and pipelines. Hard waxes utilize a higher temperature to melt, so wax can build up over time and block production lines. Therefore, there is a need for a more effective and cost-saving composition or method to limit the precipitation or agglomeration of wax, paraffin, asphaltenes, and other high molecular weight components during operations.

[0023] The present disclosure relates to a composition that may be used to treat hydrocarbon reservoirs with hydrocarbon fluids (e.g., petroleum fluid) that includes high molecular weight components. The composition may further be utilized in a hydrocarbon extraction system or otherwise provided to a subsurface environment to stabilize the high molecular weight components within the hydrocarbon fluid, such that the high molecular weight components are prevented from agglomerating or precipitating. For example, the composition may reduce a precipitation rate or otherwise increase the time period that the high molecular weight components are dispersed in the hydrocarbon fluids. In this way, precipitation may occur in a more desirable location that is generally not within reservoirs, wellbore tubing, flowlines, separators, and other components of hydrocarbon production systems.

[0024] The composition includes a hyperbranched polymer. As referred to herein, a “hyperbranched polymer” refers to a polymer that includes multiple branches (e.g., a branch is a chain of atoms having a length of at least two atoms) and has a three-dimensional structure. As compared to dendrimers, hyperbranched polymers have an irregular branching,IS25.0295 (SCFT:0420) such that one or more of the lengths of each branch may vary, spacing (e.g., number of atoms between nodes of branches) may vary, or any combination thereof. The hyperbranched polymer may include a main anchoring backbone functionalized with pendant chains with one or more polar functional groups. The functionalized pendant chains may be terminal functional groups of the hyperbranched polymer. The polar functional groups may include hydroxyl functional groups, carboxylic acid functional groups, amine functional groups, phosphate functional groups, sulfate functional groups, anhydride functional groups, or other types of polar functional groups (e.g., having a bond between carbon and a group 15 or group 16 element). Without wishing to be bound by theory, it is believed that the polar functional groups may help isolate certain high molecular weight components from each other within the petroleum or other hydrocarbon fluid. In this way, the presence of the polar functional groups may substantially reduce or prevent agglomeration or precipitation. The composition also includes a hydrocarbon solvent to facilitate injecting or otherwise providing the hyperbranched polymer to a reservoir or other fluid-containing location of a subsurface environment.

[0025] In some embodiments, the hyperbranched polymer may include a dendrimer core with a plurality of carbon-containing branches (e.g., alkyl branches, alkenyl branches, or both). For example, FIG. 1 is a flow diagram of a process 10 for generating and utilizing an inhibitor composition (e.g., an asphaltene inhibitor composition, a paraffin inhibitor composition, a wax inhibitor composition), in accordance with the present disclosure. It should be noted that the example process 10 shown in FIG. 1 is not limiting, and the process 10 may include additional or fewer blocks than those illustrated. Further, the process 10 may include block that are performed in an alternative order to that illustrated. That is, certain blocks may be performed before, after, or concurrently to / with another respective step.

[0026] Referring to the process 10, at block 12, a hyperbranched polymer 14 and a hydrocarbon solvent 16 are combined or provided to produce the inhibitor composition 18. In some embodiments, one or more alkylated polymers 20, one or more additives 22, or both, may be added to produce the inhibitor composition 18. For example, the hyperbranched polymer 14, the hydrocarbon solvent 16, and other components (e.g., the alkylated polymersIS25.0295 (SCFT:0420)20, the additives 22, etc.) may be co-fed into a vessel or fed or otherwise provided separately into the vessel.

[0027] The hydrocarbon solvent 16 may be selected from the group consisting of aliphatic hydrocarbons, organic esters, aromatic hydrocarbons, cyclic hydrocarbons ethers, alcohols, amines either individually or in combinations thereof. In some embodiments, the hydrocarbon solvent 16 may include a mixture of one or more of these solvents. As a nonlimiting example, the hydrocarbon solvent 16 may include one or more of toluene, xylene, a C12, Cl 1, CIO, C9, C8, or lower carbon-containing aromatic fluid having a relatively low naphthalene content (e.g., less than 0.9 wt%). As one specific example, the hydrocarbon solvent 16 may be SOLVESSO (e.g., SOLVESSO 150 ND manufactured by ExxonMobil Chemical) or other suitable aromatic fluids.

[0028] The hyperbranched polymer 14 includes a main anchoring backbone functionalized with different stabilizing polymeric chains with at least two polar functional groups. The main anchoring backbone may be carbon chains that extend from a main carbon chain having 8 or more carbons. The two polar functional groups (e.g., polar nucleophilic functional groups) may include one or more of a hydroxyl functional group, a carboxylic functional group, an amine functional group (e.g., primary, secondary, or tertiary amine), an anhydride functional group, an epoxide functional group, a sulfate functional group, a phosphate functional group, and other nucleophilic functional groups. As non-limiting examples, the hyperbranched polymer 14 may have a similar structure to hyperdispersant additives used in printing inks, conducting inkjet inks and conductive inkjet coatings, such as UBEDISP polymers (e.g., UBEDISP E101, UBEDISP E103, and the like manufactured by UBE Corporation Europe). The hyperbranched polymer 14 may have a viscosity (e.g., dynamic viscosity) between 50 cps and 3000 cps at 75°C, such as between 100 cps and 3000 cps, 200 cps and 2000 cps, or 500 cps and 3000 cps at 75 °C. In some embodiments, the hyperbranched polymer 14 may have a viscosity that is greater than 3000 cps at 80°C. In some embodiments, the hyperbranched polymer 14 may have a viscosity that is between 5000 to 20000 cps at 40°C.IS25.0295 (SCFT:0420)

[0029] The hyperbranched polymer 14 may also be characterized by an amine value indicating the amount of amine functional groups present. For example, the hyperbranched polymer 14 may have an amine value between 1 to 10 mg KOH / g, between 1 to 20 mg KOH / g, between 1 to 50 mg KOH / g, between 1 to 60 mg KOH / g, between 1 to 75 mg KOH / g, or greater than 75 mg KOH / g. The hyperbranched polymer 14 may also be characterized by an acid value indicating the amount of carboxylic functional groups present. For example, the hyperbranched polymer 14 may have an amine value between 1 to 10 mg KOH / g, between 1 to 20 mg KOH / g, between 1 to 30 mg KOH / g, between 1 to 40 mg KOH / g, between 1 to 50 mg KOH / g, or greater than 50 mg KOH / g. The hyperbranched polymer 14 may have a flash point greater than or equal to 200 °C, 210 °C, 220 °C, 230 °C, 240 °C, or 250 °C.

[0030] The alkylated polymer 20 may include C5-C30 pendant carbon chains, such as C16-C24 pendant carbon chain or CIO to C25 pendant carbon chains. In some embodiments, the alkylated polymer 20 is an an alkylated phenol polymer. For example, the alkylated polymer 20 may include FLOZOL 2252H from Lubrizol corporation, UK, or CERIFLOW 4610, from SI group, USA.

[0031] The additives 22 may include a functionalized dendrimer. For example, the functionalized dendrimer may be the product of a reaction between a dendrimer functionalized with hydroxyl groups and polyalkylene-substituted anhydrides. As one specific example, the polyalkylene-substituted anhydride may include polyisobutylenesubstituted succinic anhydride. The functionalized dendrimer and the polyalkylene- substituted anhydride may be mixed in the presence of a solvent (e.g., a hydrocarbon solvent). The functionalized dendrimer and the polyalkylene-substituted anhydride may be mixed or otherwise combined at a molar ratio of 10: 1 to 30: 1 with respect to functionalized dendrimer to polyalkylene-substituted anhydride. For example, the molar ratio of the functionalized dendrimer to the polyalkylene-substituted anhydride 16 may be between 5: 1 and 15: 1, 3: 1 and 10:1, 1 : 1 and 5: 1, and so on.

[0032] The functionalized dendrimer of the additives 22 may include suitable functional groups that react with the oxygen between the carboxyls of the anhydride functional group polyalkylene-substituted anhydride. For example, the functionalized dendrimer may includeIS25.0295 (SCFT:0420) polar functional groups, such as hydroxl functional groups, amine functional groups, carboxyl functional groups, and other polar functional groups discussed herein. The polyalkenes of the polyalkylene-substituted anhydride may be a carbon chain with additional branches such as polyisopropylene or polyisobutylene or a carbon chain without branches (e.g., an alkyl chain). The anhydride of the polyalkylene-substituted anhydride may be succinic anhydride or other cyclic anhydrides.

[0033] The hyperbranched polymer 14, the one or more alkylated polymer 20, and the hydrocarbon solvent 26 may be mixed, such that a total weight percentage (wt%) of the inhibitor composition 18 includes 1 to 50 wt% of the one or more alkylated polymer 20. For example, the inhibitor composition 18 may include between 1 to 40 wt%, 1 to 30 wt%, 1 to 20 wt%, or 1 to 10 wt% of the alkylated polymer 20 (e.g., combined weight percentage of one or more alkylated polymer 20). The inhibitor composition 18 may include 1 to 50 wt% of the hyperbranched polymer 14. For example, the inhibitor composition 18 may include between 1 to 40 wt%, 1 to 30 wt%, 1 to 20 wt%, or 1 to 10 wt% of the hyperbranched polymer 14. The remainder may be the hydrocarbon solvent 26 to sum up to 100 wt%. In some embodiments, the inhibitor composition 18 may include between 50 and 99 wt% of the hydrocarbon solvent 26. For example, the inhibitor composition 18 may include between 50 to 90 wt%, 50 to 80 wt%, 60 to 90 wt%, 60 to 80 wt%, 75 to 99 wt%, or 75 to 95 wt% of the hydrocarbon solvent 26.

[0034] Referring to the process 10, at block 24, the inhibitor composition 18 may be provided to a wellbore to treat a subterranean formation, which is further described in FIG. 2. The inhibitor composition 18 may be provided to the wellbore and / or a formation (e.g., natural fractures, channels, fissures, high permeability strikes) within the wellbore or equipment utilized in the wellbore (e.g., tubings) where a petroleum or hydrocarbon fluid is extracted from the wellbore or other subterranean location (e g., a subsea location) to substantially reduce or prevent agglomeration of high molecular weight components. The formations / zones may be fluidly coupled to the wellbore. It should be noted that the inhibitor composition 18 may be injected into various different positions to be added to fluids from the subterranean formation and / or to enter a subterranean formation, such as tubing, wellheads,IS25.0295 (SCFT:0420) flowlines, pipeline functions, storage facilities, and other positions downstream of wellheads. The amount of the inhibitor composition 18 provided to the subterranean formation may be a sufficient amount, such that the petroleum fluid (e.g., crude oil, fuel oil, lubricating oil, or any combination thereof) being utilized or extracted includes between 0.001% to 0.5%, 0.01% to 0.2%, 0.01% to 0.5%, 0.01% to 0.5%, or 0.01% to 0.05% concentration of the inhibitor composition 18. Accordingly, the inhibitor composition 18 may be injected into the wellbore and / or the formation via the one or more vessels, such that it may substantially reduce or prevent agglomeration that may plug or reduce the flow rate of a fluid being extracted from the subterranean formation. Tn this way, the inhibitor composition 18 may improve the efficiency of hydrocarbon extraction operations by prevent undesirable plugging resulting from agglomeration or precipitation of heavy molecular weight components, such as paraffins, waxes, asphaltenes, or a combination thereof.

[0035] With the foregoing in mind, FIG. 2 is an example system 100 that may be used to treat a subterranean environment, such as a wellbore 102 and / or a formation 104 fluidly coupled to the wellbore 102 using the inhibitor composition 18. The formation 104 may be any type of formation with a bottom hole temperature up to about 204° C. (400°F). For example, the temperature may be about 38° C (100° F), such as ranging from about 38° C to about 204°C. In the illustrated diagram, the wellbore 102 is depicted as a vertical, cased and cemented wellbore 102, having perforations providing fluid communication between the formation 104 and the interior of the wellbore 102. However, the particular features of the wellbore 102 are not limiting, and the example provides an example context 100 for a procedure. Although shown as a formation under a surface, it should be noted that the disclosed techniques may also be used to treat subsea formations.

[0036] The system 100 may include a high-pressure pump 106 having a source of the inhibitor composition 18, as described herein. The high-pressure pump 106 may be fluidly coupled to the wellbore 102, through high-pressure lines 108 in the example. The example system 100 includes tubing 110 (e.g., one or more vessels) in the wellbore 102. It should be noted that the tubing 110 may be optional and non-limiting. In various embodiments, the tubing 110 may be omitted, a coiled tubing unit (not shown) may be present, and / orIS25.0295 (SCFT:0420) the high-pressure pump 106 may be fluidly coupled to the casing or annulus 122. The tubing or casing may be made of steel.

[0037] In certain embodiments, one or more additives may be added to the wellbore 102 and / or the formation 104 in addition to the inhibitor composition 18 to provide, or as a part of, an oilfield treatment fluid. Additives may be added at a blender, at a mixing tub of the high-pressure pump 106, and / or by any other method. For example, the additives may be co-fed or fed separately from the inhibitor composition 18.

[0038] The high-pressure pump 106 can treat (e.g., plug) the wellbore 102 and / or the formation 104, for example by positioning fluid therein, by injecting the fluid into the wellbore 102, and / or by injecting the fluid into the formation 104. Example and nonlimiting fluids include any oilfield treatment fluids without limitation. Potential fluid flows include flowing from the high-pressure pump 106 into the tubing 110, into the formation 104, and / or into the annulus 112. The inhibitor composition 18 may be recirculated out of the well before entering the formation 104, for example utilizing a back side pump 114.Examples

[0039] Several inhibitor compositions 18 were tested against controls. A first example inhibitor composition 18 included 5g of Flozol 2252H, 5g of Ceriflow 4610 and 10g UBEDISP E103 wax mixed in 80g Solvesso 150ND solvent. A first control included 15g of Flozol 2252H wax mixed in 85g of Solvesso 150ND. A second control included 15g Ceriflow 4610 wax mixed in 85g of Solvesso 150ND.

[0040] Wax / Paraffin Inhibition Test

[0041] Example 1 (e.g., the first example), Example 2 (e.g., the second example), and Example 3 (e.g., the third example) were screened for wax inhibition at 1500ppm on waxy production fluids. For the inhibition test, production fluids used were obtained from the North Sea region.IS25.0295 (SCFT:0420)

[0042] A cold finger test is used to assess the performance of the wax inhibitor. Petroleum fluid from south Texas was heated at 65°C in a water bath. An 80ml of each heated fluid sample was taken in a glass jar, and Example 1, Example 2, and Example 3 were injected at 1500 ppm in each glass jar. Upon addition of wax inhibitor, the glass jars are sealed and shaken before being placed back to the water bath at 65°C for 30 minutes. The glass jars are then attached to a cold finger unit and the glass jars are then immersed into the water bath which are preheated to 65°C with constant stirring. After 30 minutes, the test is started by setting water bath temperature to 27°C and cold finger temperature is set at 4°C. After 20 hours under these conditions, the glass jars are removed from the water bath and from cold fingers subsequently.

[0043] The wax deposit is collected from each glass jar of Example 1, Example 2, and Example 3, and weighed. All Example 1, Example 2, and Example 3 wax inhibition percentages are calculated for each treatment applied to the untread petroleum fluid collected from the North Sea Region.

[0044] Percentage (%) wax inhibition is calculated using the formula below:

[0045] Table 1 below highlights the test results of the cold finger test for Example 1,Example 2, and Example 3.Table 1 : Cold Finger test results

[0046] Example 3 was assessed for subsea stability under extreme environments as shown in Table 2 below. Example 3 was kept at -10°C subsea, 4°C Seafloor, Ambient and high 55°C environment to assess the stability.IS25.0295 (SCFT:0420)Table 2: Seafloor Temperature Stability Test

[0047] The results of Example 3 in Table 1 and Table 2, which indicates low paraffin inhibition % as well as flow stability at -10°C, revealed that Example 3 is stable for a subsea application.Additional Examples

[0048] Several examples of inhibitor compositions 18 were tested against controls. The fourth example (e.g., Example 4) include a first inhibitor composition that includes 25g UBEDISP E101 mixed in 75g SOLVESSO 150ND solvent. The fifth example (e.g., Example 5) includes a second inhibitor composition 18 that includes 25g UBEDISP E1004D mixed in 75g SOLVESSO 150ND.

[0049] Asphaltene Dispersion Test (ADT)

[0050] An Asphaltene Dispersion Test is widely used to screen and evaluate the asphaltene dispersant in the oil and gas industry. The examples above were screened for wax inhibition at 1500ppm on waxy production fluids. The procedure is used for comparing the asphaltene content of crude oils and evaluating the ability of asphaltene dispersant to disperse asphaltenes.

[0051] In an example ADT method, heptane is chosen as the solvent. Heptane is a nonpolar solvent and promotes the agglomeration and precipitation of polar asphaltene. The better the dispersant is, the more of the asphaltene will be dispersed in the treated heptane and less precipitation will be observed with various time intervals. Blank crude oil concentration was found by adding different concentrations of crude oil in a 10ml graduated centrifuge tube containing 10ml of heptane. The tubes were allowed to stand for 2 hours. A crude oil concentration was chosen which shows 4-10% asphaltene precipitation.

[0052] In other tubes, a known concentration of crude oil containing a heptane and a precalculated dose rate of the above asphaltene dispersants The examples were added andIS25.0295 (SCFT:0420) shaken well. All the tubes along with blank crude oil were allowed to stand for up to 2 hours. The percentage (%) asphaltene precipitation for blank and relative % asphaltene dispersant was calculated as shown in the table below. In general, the dispersion is calculated in a similar manner as shown in Equation 1, but with asphaltenes instead of wax.Table 3: Asphaltene dispersion test results

[0053] The technical effect of the disclosed embodiments includes a composition that may reduce a precipitation rate or otherwise increase the time period that the high molecular weight components are dispersed in the hydrocarbon fluids. Without wishing to be bound by theory, it is believed that the polar functional groups may help isolate certain high molecular weight components from each other within the petroleum or other hydrocarbon fluid. In this way, the presence of the polar functional groups may substantially reduce or prevent agglomeration or precipitation. The composition also includes a hydrocarbon solvent to facilitate injecting or otherwise providing the hyperbranched polymer to a reservoir or other fluid-containing location of a subsurface environment.

[0054] The subject matter described in detail above may be defined by one or more clauses, as set forth below.

[0055] An inhibitor composition, including a hyperbranched polymer in an amount of 1 to 50 weight percentage of total weight of the inhibitor composition, wherein the hyperbranched polymer includes a main anchoring group with functionalized pendant chains with at least two polar functional groups; and at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.IS25.0295 (SCFT:0420)

[0056] The inhibitor composition of any preceding clause, wherein the at least two polar functional groups include one or more hydroxyl functional groups, one or more carboxylic functional groups, one or more amine functional groups, one or more sulfate functional groups, one or more phosphate functional groups, one or more anhydride functional groups, or a combination thereof.

[0057] The inhibitor composition of any preceding clause, including at least one alkylated polymer in an amount of 1 to 50 weight percentage of a total weight of the inhibitor composition.

[0058] The inhibitor composition of any preceding clause, wherein the at least one alkylated polymer includes an alkylated phenol polymer.

[0059] The inhibitor composition of any preceding clause, wherein the at least one alkylated polymer includes a C5-C30 pendant carbon chain.

[0060] The inhibitor composition of any preceding clause, wherein the at least one alkylated polymer includes a C16-C24 pendant carbon chain.

[0061] The inhibitor composition of any preceding clause, including the alkylated polymer in an amount of 1 to 20 weight percentage of the total weight of the composition.

[0062] The inhibitor composition of any preceding clause, wherein the inhibitor composition is added to a petroleum fluid including crude oil, fuel oil, lubricating oil, or a combination thereof.

[0063] The inhibitor composition of any preceding clause, including the hydrocarbon solvent in an amount of 75 to 99 weight percentage of the total weight of the composition.

[0064] The inhibitor composition of any preceding clause, including the hyperbranched polymer in an amount of 1 to 20 weight percentage.

[0065] A petroleum fluid including 0.01% to 0.1% concentration of the inhibitor composition of the inhibitor composition of any preceding clause.IS25.0295 (SCFT:0420)

[0066] The inhibitor composition of any preceding clause, wherein the at least one hydrocarbon solvents are selected from the group consisting of aliphatic hydrocarbons, organic esters, aromatic hydrocarbons, cyclic hydrocarbons ethers, alcohols, amines either individually or in combinations thereof.

[0067] The inhibitor composition of any preceding clause, wherein the at least one hydrocarbon solvents includes the aromatic hydrocarbons.

[0068] The inhibitor composition of any preceding clause, wherein the functionalized pendant chains are terminal functional groups of the hyperbranched polymer.

[0069] A method, including: obtaining an inhibitor composition, wherein the inhibitor composition includes: at least one alkylated polymer in an amount of 1 to 50 weight percentage of total weight of the composition; a hyperbranched polymer in an amount of 1 to 50 weight percentage of total weight of the composition, wherein the hyperbranched polymer includes a main anchoring group with functionalized pendant chains with at least two functional groups, wherein the at least two functional groups include one or more hydroxyl functional groups, one or more carboxylic functional groups, one or more amine functional groups, or a combination thereof; at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the composition; and injecting the inhibitor composition into a subterranean environment.

[0070] The method of any preceding clause, wherein the subterranean environment includes paraffins, asphaltenes, or a combination thereof.

[0071] The method of any preceding clause, wherein obtaining the inhibitor composition includes combining a functionalized dendrimer with polyalkylene-substituted anhydride to generate the hyperbranched polymer.

[0072] The method of any preceding clause, wherein the polyalkylene-substituted anhydride is polyisobutylene-substituted succinic anhydride.IS25.0295 (SCFT:0420)

[0073] The method of any preceding clause, including combining the functionalized dendrimer with the polyalkylene-substituted anhydride at a molar ratio of 10: 1 to 30: 1 with respect to functionalized dendrimer to polyalkylene-substituted anhydride.

[0074] A system, including a vessel disposed in a subterranean environment, wherein the vessel includes an inhibitor composition, wherein the inhibitor composition includes at least one alkylated polymer, additives, or a combination thereof, in an amount of 1 to 50 weight percentage of total weight of the composition; a hyperbranched polymer in an amount of 1 to 50 weight percentage of total weight of the composition, wherein the hyperbranched polymer includes a main anchoring group with functionalized pendant chains with at least two polar functional groups; and at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the composition.

[0075] The foregoing description, for purpose of explanation, has been described with reference to specific embodiments. However, the illustrative discussions above are not intended to be exhaustive or to limit the disclosure to the precise forms disclosed. Many modifications and variations are possible in view of the above teachings. Moreover, the order in which the elements of the methods described herein are illustrated and described may be re-arranged, and / or two or more elements may occur simultaneously. The embodiments were chosen and described in order to best explain the principals of the disclosure and its practical applications, to thereby enable others skilled in the art to best utilize the disclosure and various embodiments with various modifications as are suited to the particular use contemplated.

Claims

IS25.0295 (SCFT:0420)CLAIMS1. An inhibitor composition, comprising: a hyperbranched polymer in an amount of 1 to 50 weight percentage of a total weight of the inhibitor composition, wherein the hyperbranched polymer comprises a main anchoring group with functionalized pendant chains with at least two polar functional groups; and at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.

2. The inhibitor composition of claim 1, wherein the at least two polar functional groups comprise one or more hydroxyl functional groups, one or more carboxylic functional groups, one or more amine functional groups, one or more sulfate functional groups, one or more phosphate functional groups, one or more anhydride functional groups, or a combination thereof.

3. The inhibitor composition of claim 1, comprising at least one alkylated polymer in an amount of 1 to 50 weight percentage of the total weight of the inhibitor composition.

4. The inhibitor composition of claim 3, wherein the at least one alkylated polymer comprises an alkylated phenol polymer.

5. The inhibitor composition of claim 3, wherein the at least one alkylated polymer comprises a C5-C3O pendant carbon chain.

6. The inhibitor composition of claim 3, wherein the at least one alkylated polymer comprises a C16-C24 pendant carbon chain.

7. The inhibitor composition of claim 3, comprising the alkylated polymer in an amount of 1 to 20 weight percentage of the total weight of the inhibitor composition.IS25.0295 (SCFT:0420)8. The inhibitor composition of claim 1, wherein the at least one hydrocarbon solvent is selected from a group consisting of aliphatic hydrocarbons, organic esters, aromatic hydrocarbons, cyclic hydrocarbons ethers, alcohols, amines either individually or in combinations thereof.

9. The inhibitor composition of claim 1, further comprising a crude oil, fuel oil, lubricating oil, or a combination thereof.

10. The inhibitor composition of claim 1 , comprising the at least one hydrocarbon solvent in an amount of 75 to 99 weight percentage of the total weight of the inhibitor composition.

11. The inhibitor composition of claim 1, comprising the hyperbranched polymer in an amount of 1 to 20 weight percentage of the total weight of the inhibitor composition.

12. The inhibitor composition of claim 11, wherein the at least one hydrocarbon solvent comprises aromatic hydrocarbons.

13. The inhibitor composition of claim 1, wherein the functionalized pendant chains are terminal functional groups of the hyperbranched polymer.

14. A petroleum fluid comprising 0.01% to 0.1% concentration of the inhibitor composition of claim 1.

15. A method, comprising: obtaining an inhibitor composition, wherein the inhibitor composition comprises: at least one alkylated polymer in an amount of 1 to 50 weight percentage of a total weight of the inhibitor composition; a hyperbranched polymer in an amount of 1 to 50 weight percentage of the total weight of the inhibitor composition, wherein the hyperbranchedIS25.0295 (SCFT:0420) polymer comprises a main anchoring group with functionalized pendant chains with at least two functional groups, wherein the at least two functional groups comprise one or more hydroxyl functional groups, one or more carboxylic functional groups, one or more amine functional groups, or any combination thereof; at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition; and injecting the inhibitor composition into a subterranean environment.

16. The method of claim 15, wherein the subterranean environment comprises paraffins, asphaltenes, or any combination thereof.

17. The method of claim 15, wherein obtaining the inhibitor composition comprises combining a functionalized dendrimer with polyalkylene-substituted anhydride to generate the hyperbranched polymer.

18. The method of claim 17, wherein the polyalkylene-substituted anhydride is polyisobutylene-substituted succinic anhydride.

19. The method of claim 18, comprising combining the functionalized dendrimer with the polyalkylene-substituted anhydride at a molar ratio of 10: 1 to 30: 1 with respect to functionalized dendrimer to polyalkylene-substituted anhydride.

20. A system, comprising: a vessel disposed in a subterranean environment, wherein the vessel comprises an inhibitor composition, wherein the inhibitor composition comprises: at least one alkylated polymer, additives, or any combination thereof, in an amount of 1 to 50 weight percentage of a total weight of the inhibitor composition; a hyperbranched polymer in an amount of 1 to 50 weight percentage of the total weight of the inhibitor composition, wherein the hyperbranched polymerIS25.0295 (SCFT:0420) comprises a main anchoring group with functionalized pendant chains with at least two polar functional groups; and at least one hydrocarbon solvent in an amount of 50 to 99 weight percentage of the total weight of the inhibitor composition.

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