A method is disclosed comprising determining a concentration of one or more compounds of a fluid in an industrial water operation in real time. The determining of the concentration of the one or more components comprises contacting an array of sensors of a microelectromechanical system (MEMS) device with a sample of the fluid to provide a sample response indicative of the concentration of the one or more components. The method further provides adjusting or maintaining at least one operating parameter of the industrial water operation based on the concentration of the one or more components of the fluid.
A method of wax treatment in subsea well may comprise providing a treatment fluid comprising a base fluid and a hyperbranched polymeric additive. The method may further comprise introducing the treatment fluid into the subsea well through an umbilical line.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
3.
MULTIFUNCTIONAL SURFACTANT AND CORROSION INHIBITOR ADDITIVES
Multifunctional surfactants useful in, for example, in the oil and gas industry, are provided, in some embodiments, the.multifunctional surfactants include at least one amide group and at least one thiol group in the same molecule.· in some embodiments, the methods include contacting a metal surface with at least one multi functional additive that includes at least one amide group and at least one thiol group in the same molecule; and allowing the multifunctional additive, to interact with at least a portion of the metal surface.
E21B 41/02 - Equipment or details not covered by groups in situ inhibition of corrosion in boreholes or wells
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
4.
SCREENING METHOD FOR FRICTION REDUCER PRECIPITATION
A method of preparing a fracturing fluid comprising: preparing or providing an aqueous fluid containing iron ions; screening a plurality of friction reducers against the aqueous fluid wherein the plurality of friction reducers are anionic, cationic, nonionic, amphoteric, or combinations thereof; selecting at least one friction reducer from the plurality of friction reducers based at least in part on the step of screening; and preparing a fracturing fluid including the at least one friction reducer.
A method may include: preparing or providing an aqueous fluid containing iron ions; screening at least one iron control agent against the aqueous fluid; selecting at least one iron control agent and iron control agent concentration based at least in part on the step of screening; and preparing a fracturing fluid comprising an aqueous base fluid and the at least one iron control agent wherein a concentration of the iron control agent in the fracturing fluid is greater than or equal to the selected iron control agent concentration.
Compositions and methods of using of such compositions to, for example, inhibit shale are provided. In one embodiment, the methods include introducing an additive including a cationic clay stabilizer and an anionic clay stabilizer into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation. In some embodiments, the methods include introducing an additive including a cationic shale inhibitor and an anionic shale inhibitor into a treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
An apparatus may include: a body defining a flow path; an inlet to the flow path; an outlet to the flow path; a test coupon at least partially disposed within the flow path; a sealing element disposed between the test coupon and the body; and a current source electrically coupled to the test coupon, wherein the inlet and the outlet are in fluid communication through the flow path, and wherein the sealing element electrically insulates the body and the test coupon
A system may include: a crude oil desalter; one or more sample points fluidically coupled to the crude oil desalter; and one or more fluid characterization units coupled to each of the one or more sample points, the one or more fluid characterization units being operable to measure at least one of density or flow rate of fluid from the sample points.
A method may include: generating a signal in a conduit; measuring the signal; generating data representing a deposit in the conduit, the data being generated by a deposition identification model, wherein the deposition identification model utilizes the signal as an input; generating a treatment plan based at least in part on the data representing the deposit; and applying a chemical additive to the conduit based at least in part on the treatment plan.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 41/00 - Equipment or details not covered by groups
Methods for treating a subterranean formation using treatment fluids including a weakly emulsifying surfactant are provided. In one or more embodiments,: the methods include introducing a first treatment fluid comprising a base fluid and. a -weakly emulsi fy ing surfactant into a first wellbore penetrating at least a first portion of a subterranean formation; and introducing a second: treatment fluid into a second wellbore penetrating at least a second portion of the subterranean formation at: a pressure sufficient to create or enhance one or more fractures: extending from the second wellbore into the subterranean formation.
These drawings Illustrate certain aspects of some of the embodiments of the present.disclosure, and should not be used to limit or define the claims. FIG. 1 is a schematic diagram of an acrolein injection system and acrolein leak detection and alert system that may be used in accordance with certain embodiments of the present disclosure. FIG. 2 is another schematic diagram of an acrolein injection system and acrolein leak detection and alert: system that may be used in accordance with certain embodiments of the present disclosure.. FIG. 3 is another schematic diagram of an acrolein injection system and acrolein leak detection and alert system that may be used in accordance with certain embodiments of the present disclosure. FIG. 4 is a diagram illustrating an example of a wellbore drilling assembly that may be used in accordance with certain embodiments of the present disclosure. While embodiments: of this disclosure have been depicted, such embodiments do not imply a limitation on the disclosure., and no such limitation should be. inferred. The subject matter disclosed is capable of considerable modification, alteration, and equivalents in form: and function, as will occur to those skilled in the pertinent art and having the benefit of this disclosure. The depicted and described embodiments of this disclosure are examples only, and not exhaustive of the scope of the disclosure.
Methods for providing corrosion inhibition in conduits, containers, and wellbores penetrating subterranean formations are provided. In some embodiments, the methods include contacting a metal surface with a fluid that includes a corrosion inhibitor additive, in certain embodiments, the corrosion inhibitor additive includes an tonic liquid.
Low-dosage hydrate inhibitor additives and methods of using such additives to, for example, inhibit the formation of gas hydrate agglomerates are provided. In some embodiments, introducing a low-dosage hydrate inhibitor additive into a fluid including at least one component selected from the group consisting of: water, a gas, a liquid hydrocarbon, and any combination thereof, wherein the low-dosage hydrate inhibitor additive includes at least one compound having the structural formula: wherein each of R1, R2, and R3166 hydrocarbon chain, wherein R415050 hydrocarbon chain, and wherein X' is selected from the group consisting of wherein R5 is a methyl or ethyl group, and any combination thereof.
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C07C 237/10 - Carboxylic acid amides, the carbon skeleton of the acid part being further substituted by amino groups having the carbon atoms of the carboxamide groups bound to acyclic carbon atoms of the carbon skeleton the carbon skeleton being acyclic and saturated having the nitrogen atom of at least one of the carboxamide groups bound to an acyclic carbon atom of a hydrocarbon radical substituted by nitrogen atoms not being part of nitro or nitroso groups
Dual cation hydrate inhibitor compositions and methods of using such compositions to, for example, inhibit the formation of gas hydrate agglomerates are provided. In some embodiments, such methods include introducing a hydrate inhibitor composition into a fluid, wherein the hydrate inhibitor composition includes at least one compound having the structural formula: wherein each of R1, R2and R3166 hydrocarbon chain, wherein R415050 hydrocarbon chain, wherein each of R5and R615050 hydrocarbon chain, wherein X_and Y_ are counter anions, and wherein each of a and b is independently an integer from 1 to 10.
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
15.
METHODS AND COMPOSITIONS FOR REDUCING CORROSIVITY OF AQUEOUS FLUIDS
Methods and compositions for treating aqueous fluids that may be included in treatment fluids that are used for treating a subterranean formation. In some embodiments, the methods include: providing a treatment fluid including an aqueous fluid and a composition that includes an oxygen scavenger, a pH-adjusting agent, and a corrosion inhibitor, wherein the aqueous fluid is aerated; contacting a metal surface with the treatment fluid; and introducing the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation.
A method and system for identifying a surfactant to use in an unconventional liquid reservoir. The method may comprise testing a core sample for spontaneous imbibition data, identifying a scaling group that correlates to the spontaneous imbibition data, identifying at least one surfactant based at least in part on the scaling group for use in the unconventional liquid reservoir, and injecting the at least one surfactant into the unconventional liquid reservoir. The system may comprise a processing unit and a non-transitory computer-readable media coupled to the processing unit, wherein the non-transitory computer-readable media stores a program. The program may be configured to simulate a well system and implement a scaling group that correlates to imbibition data. The system may further comprise identify at least one surfactant based at least in part on the scaling group for use in the unconventional liquid reservoir.
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method may comprise introducing a first traceable solid particulate into a first formation zone of one or more subterranean formations, wherein the first traceable solid particulate may comprise a first soluble tracer coated onto a first solid particulate. The method may also comprise introducing a second traceable solid particulate into a second formation zone of the one or more subterranean formations, wherein the second traceable solid particulate may comprise a second soluble tracer coated onto a second solid particulate, wherein the second tracer and the first tracer may have a different chemical identity. The method may further comprise recovering produced fluid from the one or more subterranean formations and monitoring concentrations of at least the first soluble tracer and the second soluble tracer in the produced fluid.
Methods for the use of zine ammonium carbonate as a scavenger of sulfur-containing species encountered in oilfield: operations are provided, in one embodiment, the methods include introducing a sulfide scavenging additive including zinc ammonium carbonate into at least a portion of a conduit through-which a potential sulfur-containing fluid is flowing.
A low dosage hydrate inhibitor blend comprising a cationic surfactant and a co- surfactant. The cationic surfactant has the structural formula: wherein: R1 is an alkyl group or alkenyl group having from 5 to 22 carbon atoms, R2 and R3 are alkyl groups having from 1 to 6 carbon atoms, R4 is a hydrogen atom or an alkyl group having from 1 to 6 carbon atoms, and X- is selected from the group of a carboxylate, an acrylate, a methacrylate, a halide, a phosphonate, a sulfate, a sulfonate, a hydroxide, a carbonate, or any combination thereof; and The co-surfactant is present in the inhibitor blend in an amount of no greater than about 10 percent by weight based on the total weight of the blend.
C09K 8/584 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific surfactants
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
A method may include: determining a total dissolved solids (TDS) concentration of a water source; correlating the TDS concentration to an ion concentration; and selecting at least one friction reducing polymer for a hydraulic fracturing operation based at least in part on the ion concentration.
A low dosage hydrate inhibitor blend and a method of treating a well fluid are provided. The low dosage inhibitor blend, which is used in the method, comprises a first cationic surfactant and a second cationic surfactant. For example, the combination of the first and second cationic surfactants in the low dosage inhibitor blend achieves a synergistic effect on the ability of the inhibitor blend to mitigate problems caused by the formation of gas hydrates in a well fluid.
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C10L 3/10 - Working-up natural gas or synthetic natural gas
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
22.
FRICTION REDUCING ADDITIVES INCLUDING NANOPARTICLES
Compositions and methods for use in fracturing treatments using friction reducing additives that include nanoparticles are provided. In some embodiments, the methods include: providing a treatment fluid that includes an aqueous base fluid and a friction reducing additive, the friction reducing additive including at least one polymer and a plurality of nanoparticles; and introducing the treatment fluid into a portion of a subterranean formation at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation.
Methods involving anti-agglomerant hydrate inhibitors and polyaromatic hydrocarbons for hydrate inhibition are provided. In some embodiments, the methods include introducing a hydrate inhibitor composition including an anti-agglomerant hydrate inhibitor into a fluid including (i) water and (ii) one of gas, liquid hydrocarbon, and any combination thereof; and introducing a polyaromatic hydrocarbon into the fluid.
A method may include: drawing a slip stream sample from a cooling fluid stream, the cooling fluid stream being fluidically coupled to an outlet of a heat exchanger and an inlet of a cooling tower; introducing the slip stream sample into an expansion chamber; and measuring a concentration of hydrogen gas within a headspace of the expansion chamber.
Methods of treating a subterranean formation are described. The methods include introducing a treatment fluid that includes a friction reducing polymer (e.g., a cationic friction reducing polymer or an anionic friction reducing polymer) into the subterranean formation. The cationic friction reducing polymer is allowed to degrade and release choline chloride or polyDADMAC, which can each act as a clay stabilizer. The anionic friction reducing polymer is allowed to degrade and release AMPS, which can act as a surfactant, a scale inhibitor, a paraffin inhibitor, or an asphaltene inhibitor, or polyacrylic acid, which can act as a scale inhibitor.
Included are compositions, methods, and systems for producing and using winterized paraffin inhibitor solutions. An example composition comprises a paraffin inhibitor solution; and an additive comprising a first portion and a second portion; wherein the first portion is selected from the functional groups consisting of sulfo, phosphate, phosphonate, ester, carboxyl, hydroxyl, and any combination thereof; wherein the second portion is selected from the functional groups consisting of linear alkyl, branched alkyl, alkyl phenyl, ethoxylated branched alkyl, propoxylated branched alkyl, and any combination thereof.
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
C09K 8/536 - 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
Methods for providing corrosion inhibition in conduits, containers, and wellbores penetrating subterranean formations are provided. In some embodiments, the methods comprise contacting a metal surface with a fluid comprising a corrosion inhibitor additive. In certain embodiments, the corrosion inhibitor additive comprises a compound comprising a hydrophobic cation moiety, one or more lipophilic tails, and a linking moiety.
A multi-layer downhole drilling tool designed for directional and horizontal drilling is disclosed. The drilling tool includes a bit body including a rotational axis extending therethrough. A plurality of primary blades are disposed on exterior portions of the bit body and a plurality of secondary blades are disposed on exterior portions of the bit body between the primary blades. The drilling tool further includes a plurality of first-layer cutting elements disposed on exterior portions of the primary blades and a plurality of second-layer cutting elements disposed on exterior portions of the secondary blades. The second-layer cutting elements are track set with the first-layer cutting elements in an opposite track set configuration.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
B23P 15/32 - Making specific metal objects by operations not covered by a single other subclass or a group in this subclass cutting tools twist-drills
30.
METHODS AND TREATMENT FLUIDS FOR MICROFRACTURE CREATION AND MICROPROPPANT DELIVERY IN SUBTERRANEAN FORMATIONS
Systems, methods, and compositions for creating microfractures within subterranean formations and delivering microproppant particles into microfractures within subterranean formations are provided. In some embodiments, the methods include: providing a treatment fluid that comprises an aqueous base fluid, a surfactant, and a plurality of microproppant particles having a mean particle diameter of about 100 microns or less; introducing the treatment fluid into a subterranean formation at or above a pressure sufficient to initiate the formation of at least one microfracture within the subterranean formation; and allowing at least a portion of the microproppant particles to enter the at least one microfracture within the subterranean formation.
Methods for delivering treatment chemicals into a subterranean formation using treatment fluids that include nanoemulsions are provided. In some embodiments, the methods include providing a treatment fluid including an aqueous base fluid and a nanoemulsion including a water-soluble internal phase, a water-soluble external phase, and a surfactant, the nanoemulsion being formed by mechanically-induced shear rupturing; and introducing the treatment fluid into at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance at least one fracture in the subterranean formation.
Systems and methods having friction reducer compositions for use in subterranean treatment fluids are provided. An embodiment of the present disclosure is a method comprising: (A) forming a treatment fluid comprising: an aqueous base fluid, a friction reducer, and an alkaline buffering agent, wherein the treatment fluid has a pH in the range of about 7 to about 10; and (B) injecting the treatment fluid into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation.
The present disclosure relates to systems and methods for treating subterranean formations. An embodiment of the present disclosure is a method comprising: introducing a fluid comprising an aqueous base fluid and a friction reducer into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation; recovering at least a portion of the fluid from the wellbore; adding a reactive agent to a sample of the portion of the fluid that has been recovered from the wellbore, wherein the reactive agent reacts with the friction reducer to form a photo-detectable compound in the sample; measuring a light absorbance of the sample of the fluid that has been recovered from the wellbore at a selected wavelength of light; and using the measured absorbance and a calibration curve for the selected wavelength of light to determine the concentration of the friction reducer in the fluid that has been recovered from the wellbore.
Compositions and methods of using of such compositions to, for example, inhibit of the formation of gas hydrate agglomerates are provided. In one embodiment, the methods comprise: introducing hydrate inhibitor composition comprising a compound into a fluid, wherein the compound comprises a hydrophobic cation moiety, one or more lipophilic tails, and a linking moiety.
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C07C 233/04 - Carboxylic acid amides having carbon atoms of carboxamide groups bound to hydrogen atoms or to acyclic carbon atoms having nitrogen atoms of carboxamide groups bound to hydrogen atoms or to carbon atoms of unsubstituted hydrocarbon radicals with carbon atoms of carboxamide groups bound to carbon atoms of an acyclic saturated carbon skeleton
35.
DOUBLE-HEADED HYDRATE INHIBITORS AND METHODS OF USE
Compositions and methods of using of such compositions to, for example, inhibit of the formation of gas hydrate agglomerates are provided. In one embodiment, the methods comprise: introducing a hydrate inhibitor composition comprising a compound into a fluid, wherein the compound comprises two hydrophobic cation moieties, a lipophilic tail, and two linking moieties.
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
C07C 233/04 - Carboxylic acid amides having carbon atoms of carboxamide groups bound to hydrogen atoms or to acyclic carbon atoms having nitrogen atoms of carboxamide groups bound to hydrogen atoms or to carbon atoms of unsubstituted hydrocarbon radicals with carbon atoms of carboxamide groups bound to carbon atoms of an acyclic saturated carbon skeleton
36.
MULTI-FUNCTIONAL SURFACTANT COMPLEXES FOR USE IN SUBTERRANEAN FORMATIONS
Systems and methods for creating and/or using multi-functional surfactant complexes that may enhance surfactant treatments in subterranean formations are provided. In some embodiments, the methods comprise: providing a treatment fluid comprising an aqueous base fluid and one or more multi-functional surfactant complexes that comprise at least one surfactant and at least one polymeric additive, wherein the surfactant and the polymeric additive carry opposite charges; and introducing the treatment fluid into a well bore at a well site penetrating at least a portion of a subterranean formation.
Certain carrier-free treatment particulates comprising solid treatment chemicals and methods for their formation and of their use in subterranean formations are provided. In one embodiment, the methods comprise: providing a plurality of carrier-free treatment particulates comprising at least one solid treatment chemical and a coating at least partially disposed around an outer surface of the solid treatment chemical; and introducing the plurality of carrier-free treatment particulates into a well bore penetrating at least a portion of a subterranean formation, wherein the plurality of carrier-free treatment particulates is at least partially consumed in the subterranean formation to create a residual porosity in the portion of the subterranean formation.
Surfactant compositions for enhancing oil and/or gas production from certain subterranean formations (e.g., unconventional reservoirs), and related methods of use, are provided. In one embodiment, the methods comprise: providing a treatment fluid comprising a carrier fluid and a cationic surfactant comprising at least two hydrophobic heads that each comprise a quaternary cationic moiety; and introducing the treatment fluid into at least a portion of a subterranean formation.
Methods, compositions, and systems for scale inhibitor squeeze treatments using certain cationic surfactants are provided. In one embodiment, the methods comprise: introducing a pre-flush fluid into at least a portion of a subterranean formation, the pre-flush fluid comprising a cationic surfactant comprising two or more hydrophilic heads, at least one lipophilic tail, and one or more linking groups to which the hydrophilic heads and the lipophilic tail are bonded; and introducing a treatment fluid comprising anionic scale inhibitor into the portion of the subterranean formation after at least a portion of the pre-flush fluid has been introduced into the portion of the subterranean formation.
Composition for the removal or inactivation of hydrogen sulfide or soluble sulfide ion other species comprising ionizable sulfur (e.g., mercaptans, thiols, etc.) using compositions containing acrylate and/or derivatives thereof are provided. Methods for the removal or inactivation of hydrogen sulfide or other sulfur species in oilfield sites and other related applications using compositions containing acrylate and/or derivatives thereof are provided.
Multi-stage treatment methods for the treatment or removal of iron sulfide scales in subterranean operations and operations involving the production and/or transportation of oil and gas are provided. In one embodiment, the methods comprise: identifying one or more types of iron sulfide scale present in a portion of a subterranean formation; introducing a first treatment composition comprising an acid into at least a portion of the subterranean formation to partially dissolve the iron sulfide scale therein; and introducing a second treatment composition into the portion of the subterranean formation after the first treatment composition, the second treatment composition comprising an iron sulfide treating additive selected based at least in part on a type of iron sulfide scale identified in the subterranean formation.
Composition for the removal or inactivation of hydrogen sulfide or other species comprising ionizable sulfur (e.g., mercaptans, thiols, etc.) using compositions containing acrylonitrile and/or derivatives thereof are provided. Methods for the removal or inactivation of hydrogen sulfide or other sulfur species in oilfield sites and other related applications using compositions containing acrylonitrile and/or derivatives thereof are provided.
C09K 8/52 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
43.
ACTIVITY ENHANCED SCALE DISPERSANT FOR TREATING INORGANIC SULFIDE SCALES
The present disclosure relates to methods and compositions to control inorganic sulfide scale formations in oilfield applications, including flow lines, wellbores, and subterranean formations. An embodiment of the present disclosure is a method comprising: providing a treatment fluid comprising: a base fluid, a scale inhibitor, and a water clarifying agent; introducing the treatment fluid into a target region, wherein an inorganic cation and a sulfide anion are present in the target region; allowing the inorganic cation and the sulfide anion to form a sulfide precipitate; and using the treatment fluid to remove at least a portion of the sulfide precipitate from the target region.
Certain particulates of encapsulated treatment chemicals, and methods of and systems for their use in subterranean formations, are provided. In one embodiment, the methods comprise: providing a plurality of treatment particulates, at least one of which comprising a polymer matrix that comprises and/or encages at least one treatment chemical and a coating disposed around an outer surface of the polymer matrix; and introducing the treatment particulates into a well bore penetrating at least a portion of a subterranean formation.
Systems and methods for selecting surfactants for use in subterranean formations are provided. In one embodiment, the methods comprise: providing a sample of oil from at least a portion of a subterranean formation; measuring at least one of the total acid number (TAN) and the total base number (TBN) of the oil sample; and selecting a set of surfactants to evaluate for a treatment in at least a portion of the subterranean formation based on at least one of the TAN and the TBN of the oil sample, the set of surfactants selected from the group consisting of: a set of cationic surfactants, a set of anionic surfactants, and a set of zwitterionic surfactants.
Systems and methods for creating surfactant-polyelectrolyte complexes at a well site are provided. In one embodiment, the methods comprise: providing a first solution comprising at least one surfactant and a second solution comprising at least one polyelectrolyte; using a stop-flow mixing apparatus at a well site to mix the first and second solutions to form one or more surfactant-polyelectrolyte complexes; using a low-dose pumping apparatus at the well site to transfer the one or more surfactant-polyelectrolyte complexes from the stop-flow mixing apparatus to a blending apparatus at the well site; using the blending apparatus to mix the one or more surfactant-polyelectrolyte complexes with an aqueous base fluid to form a treatment fluid; and introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation at the well site.
Compositions and methods for formulating treatment fluids that comprise a surfactant having reduced and delayed adsorption are provided. In one embodiment, the method comprises: providing a fluid comprising: an aqueous base fluid, a surfactant, and a polyelectrolyte; introducing the fluid into a wellbore penetrating at least a portion of a subterranean formation; and contacting at least a portion of the subterranean formation with the polyelectrolyte. In another embodiment, the method comprises providing a fluid comprising: an aqueous base fluid, a surfactant, and a polyelectrolyte; injecting the fluid into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation; and contacting at least a portion of the subterranean formation with the polyelectrolyte.
Compositions, treatment fluids, and methods for providing corrosion inhibition in subterranean operations, pipelines, and other related operations are provided. In one embodiment, the methods comprise providing a tagged corrosion-inhibiting additive that comprises an imidazoline-based compound bonded with a detectable moiety; and introducing the tagged corrosion-inhibiting additive into at least a portion of a subterranean formation or pipeline.
Improved compositions, treatment fluids, and methods for providing paraffin inhibition in subterranean operations, pipelines, and other related operations are provided. In one embodiment, the methods comprise: providing a tagged inhibitor that comprises a base compound capable of inhibiting precipitation of paraffins or asphaltenes bonded with a detectable moiety; and introducing the tagged inhibitor into at least a portion of a subterranean formation.
Compounds comprising multiple hydrophilic heads and a lipophilic tail may be contacted with a metal or other surface so as to adhere to the surface and inhibit corrosion, among other things. Suitable hydrophilic heads may include quaternary ammonium cation moieties, phosphonium cation moieties, and combinations thereof. Such corrosion-inhibiting compounds may be introduced into a wellbore penetrating at least a portion of a subterranean formation, for instance in oil and/or gas recovery operations and the like, whereupon the compound may adhere to a metal or other surface downhole so as to inhibit corrosion of the surface. These compounds may be employed in various other environments, such as any metal or other surface that may be exposed to corrosive conditions.
Compounds comprising multiple hydrophilic heads and a lipophilic tail may be employed into fluids to inhibit agglomeration of hydrates, among other things. Suitable hydrophilic heads may include secondary, tertiary, and/or quaternary ammonium cation moieties, phosphonium cation moieties, and combinations thereof. Such LDHI compounds may provide enhanced interactivity with hydrate crystals and/or hydrate-forming molecules. These compounds may be employed in fluids in various environments, such as a conduit penetrating a subterranean formation, or a conduit carrying fluid in an industrial setting.
Low-dosage hydrate inhibitor ("LDHI") compounds comprising multiple lipophilic tails and a hydrophilic head may be employed into fluids to inhibit agglomeration of hydrates, among other things. Suitable hydrophilic heads may include quaternary or tertiary ammonium cation moieties, and combinations thereof. Such LDHI compounds in some embodiments may include reaction products of DETA and/or other amines, fatty acid(s), and, optionally, alkyl halide(s). Compounds according to some embodiments may be employed in fluids in various environments, such as a conduit penetrating a subterranean formation, or a conduit carrying fluid in an industrial setting.
A mini-reservoir device may be used to screen or otherwise determine a composition of one or more treatment fluids, additives, and other fluids. Such fluids may be for use in a subterranean formation. Methods of determining a composition may include visual analysis of each of two or more fluids, each from a plurality of candidate fluids, flowed through a mini-reservoir device, and selection of one of the plurality of candidate fluids based at least in part upon that visual analysis. Certain methods may include determining an oil recovery factor for each of one or more fluids flowed through a mini-reservoir device. In particular methods, multiple treatment fluids and/or additives, such as surfactants, may be selected based at least in part upon visual analysis of the fluids' flow through a mini-reservoir device.
Provided are acidic treatment fluids comprising a weakly emulsifying surfactant, an aqueous base fluid, and an acid. In some embodiments, the treatment fluids are capable of forming short-lived oil-in-acid emulsions due, at least in part, to the interaction of at least a portion of the weakly emulsifying surfactant with one or more oil or gas molecules within a subterranean formation.
A method of controlling sulfides in a fluid including determining selected conditions of the fluid and selecting a nitrogen reducing bacteria (NRB) based on those conditions. The method further includes injecting an NRB into the fluid and injecting an inorganic nitrate into the fluid.
A method of controlling a deleterious bacteria in a fluid including injecting a nitrite or nitrate into the fluid, identifying a phage capable of infecting the deleterious bacteria, and injecting the phage into the fluid.
A method of controlling sulfides in water systems is disclosed which includes injecting 9,10 anthraquinone into the water system and injecting a nitrate or nitrite into the water system.
A method of controlling a deleterious bacteria in oil and gas production, oil and gas completion fluids or other industrial fluids is described which includes identifying a phage capable of infecting the deleterious bacteria, identifying a biocide compatible with the phage and effective against the deleterious bacteria and injecting the biocide and the phage into the oil and gas production, oil and gas completion or other industrial fluid.
A method of inhibiting gas hydrate formation in petroleum and natural gas production systems through the use of low dosage hydrate inhibitors which include reaction products of non-halide-containing inorganic acids, organic acids, and organic amines. The use of these non-halide-containing reaction products rather than chloride containing acids or alkylating agents avoids corrosion and stress cracking caused by residual inorganic chloride and other inorganic, halide-containing acids. The anti-agglomerate compositions can be administered continuously to effectively inhibit gas hydrate formation. In preferred embodiments, the anti- agglomerate compositions are mixtures of reaction products of non-halide-containing organic acids and organic amines.
A method of determining the suitability of a surfactant for use in a formation can include sampling water in the formation, providing at least two surfactants, and mixing each of the surfactants with the formation water to form surfactant/water samples. The method can further include determining the solubility of each surfactant with the formation water, comparing the solubility of each surfactant with the other surfactant, and assigning a solubility performance value for each surfactant based on its solubility in the formation water sample compared to the other surfactant.
A method of controlling corrosion in a subsea pipeline is disclosed which includes supplying a low dose inhibitor stream (LDHI) comprised of a quaternary amine and drying with a desiccant.
A slick water fracturing fluid including a brine, an inorganic nitrate, a nitrogen reducing bacteria, a scale inhibitor selected from the group consisting of a polyacrylate polymer, a polyacrylate copolymer, a polyacrylate terpolymer, and mixtures thereof, and a friction reducer, wherein the friction reducer is a polyacrylamide.
An apparatus and method for remotely monitoring the temperature of acrolein in a storage tank has a temperature sensor in communication with the acrolein in the tank and with a temperature transmitter. A global positioning receiver/transmitter communicates with the temperature transmitter and sends the temperature data to a remote base station via a linking satellite while also providing location data about the storage tank. At the base station, the temperature data related to the actual temperature of the acrolein in the tank is compared to predetermined temperature set points. These predetermined set points correlate to polymerization reaction of the acrolein. When the set points are reached, a response processor initiates a response t control the polymerization reaction of the acrolein in the storage tank.
A method for scavenging hydrogen sulfide from geothermal steam in a condenser under vacuum. A fine curtain of atomized acrolein-water droplets may be sprayed into geothermal steam condensers in an amount of approximately 2:1 molar ratio of acrolein to H2S based on hydrogen sulfide in the incoming steam from the turbine. The range being approximately 0.1 ppm to 500 ppm of sulfide. The acrolein is allowed to react with the gas phase H2S to form non-volatile aldehyde byproducts which partition into the water phase, are returned to the cooling tower and ultimately removed by normal cooling-tower blow down.
01 - Chemical and biological materials for industrial, scientific and agricultural use
37 - Construction and mining; installation and repair services
Goods & Services
(1) CHEMICAL ADDITIVES USED IN GAS WELL PRODUCTION. (1) GAS WELL PRODUCTION SERVICES FOR OTHERS, NAMELY, ENHANCING PRODUCTION OF GAS FROM GAS WELLS USING CHEMICAL ADDITIVES.
67.
DETECTION OF CORROS ION- INDUCING PROKARYOTES USING THE DISSIMILATORY SULFATE REDUCTASE GENE
A simple method for the collection of field samples for nucleic acid extraction and subsequential detection of microorganisms from various media such as aqueous samples, sediments and biofilms (sessile bacteria). This method is a quantitative polymerase chain reaction (PCR)-based technique for detection of SRP in various media (i.e., aqueous samples, sediments, biofilms). The principle of this technique is based on the fact that all prokaryotes (Bacteria and Archaea) able to carry out sulfate reduction possess a gene that encodes dissimilatory sulfite reductase (DSR), the key enzyme in the sulfate reduction pathway. Microbial induced corrosion is due to bacterial growth and thus, tests for the detection of bacterial growth in fluids involved in oil processing are routinely performed. Thus far, the widely accepted methods for detection of bacterial growth of microorganisms involved in corrosion are cultivation dependent and, therefore, these methods underestimate the number of microorganisms present in a sample and require long incubation times.
Methods and systems for deliquification of fluid loaded, packed wells with sub-surface safety valves ('SSSVs') utilizing timed and tailored chemical treatments. A flow meter measures the flow rate of the well and an intermitter initiates shut in of the well when a particular flow rate is reached. A chemical treatment is applied and allowed to penetrate the length of the well before production is restarted. Predetermined combinations of chemical treatments and production cycles are utilized based on past experience and well data, and the entire process can be automated through the use of a computer system.
Defoamer compositions effective for the suppression of oil-based and water-based foams. The defoamer compositions comprise a fumed metal oxide, such as fumed silica, or another silica-based material dispersed in an organic solvent. The fumed metal oxide of silica-based material is preferably present at a low weight percentage and may be coated with polydimethylsiloxane ('PDMS'). The defoamer composition may also include one or more traditional defoamer compositions.
