Abstract: A solid surfactant composition includes a water-wetting surfactant and a plant fiber carrying agent. A process includes forming a solid surfactant composition comprising a water-wetting surfactant and a plant fiber carrying agent and injecting the solid surfactant composition into a wellbore.

Abstract: A downhole system includes a lower completion having at least one tubular including a first end and a second end terminating at a shoe. The at least one tubular defining a flow path. A packer is arranged at the first end. A fluid loss control valve (FLCV) is arranged between the packer and the shoe. A screen system is arranged between the FLCV and the shoe. The screen system includes a screen and a non-mechanically operated flow control valve that selectively isolates the flow path from formation fluids passing through the screen. A wellbore clean out string is insertable into the lower completion. The wellbore clean out string includes a selectively activated casing cleaner and a setting tool. The selectively activated casing cleaner is spaced from the setting tool.

Abstract: A method for acid treatment of a wellbore in a carbonate formation is provided. The method includes dropping spacer solids into the well to fill the wellbore to perforations in a casing, dropping acidic solids into the wellbore on the top of the spacer solids, allowing the acidic solids to dissolve on top of the spacer solids forming an acidic solution, and injecting water into the wellbore to force the acidic solution into the carbonate formation.

Abstract: A steeply-inclined ultra-thick coal seam gas control method based on a binary composite liquid. The method includes taking a clean fracturing fluid system and a microemulsion as a binary composite liquid. The method includes injecting the binary composite liquid into a coal mass by means of a main hydraulic fracturing and permeability improvement method of hydraulic fracturing and water jet slotting to form a coal mass gas extraction system of binary composite liquid fracturing and permeability improvement. The method includes investigating and analyzing a gas control effect of the steeply-inclined ultra-thick coal seam according to change characteristics and analysis of gas extraction flow rate, change characteristics and analysis of permeability coefficient of coal seam, change characteristics and analysis of gas natural desorption speed of coal mass, change characteristics and analysis of gas concentration of return air flow of working face and theoretical analysis of drilling cuttings index.

Abstract: A cutting head assembly uses multiple cutting heads directing ultra-high pressure fluid in different directions towards an inner surface of a pipe to be cut in order to complete a full cut of the pipe while rotating or revolving the multiple cutting heads less than 360 degrees relative to central axis. The ultra-high pressure fluid mixes with abrasive inside fittings on or near each of the nozzles to further assist with cutting through the pipe. Some cutting head assemblies have two nozzles, while other cutting head assemblies have three or four nozzles.

Abstract: A composition for servicing a borehole in a subterranean formation by removing a filter cake along a wall of the borehole includes a biopolymer, the composition including a carrier fluid effective to act as a transport medium; an enzymatic breaker having activity to degrade the biopolymer in the filter cake upon contact with the filter cake so as to break up the biopolymer for removal; and an enzyme inhibitor effective to slow down the activity of the enzymatic breaker; where the composition may exclude the biopolymer. A method of servicing a borehole includes contacting the filter cake with the composition; degrading the biopolymer with the enzymatic breaker to produce degraded biopolymer; slowing down the degrading activity of the breaker with the enzyme inhibitor sufficiently that the degrading comprises degrading biopolymer along a length of the wall of the borehole; and removing the filter cake from the wall of the borehole.

Abstract: A wellbore jet pump includes a nozzle body with a tapering nozzle passage therein and a pump body with a main passage that receives the nozzle body therein so as to define within the main passage (i) an intake section surrounding the nozzle body, (ii) a mixing section immediately above the nozzle body, and (iii) a diffuser section diverging upwardly from the mixing section. A bypass conduit directs a working fluid downwardly alongside the pump body and upwardly into one of the nozzle passage or the intake section so that produced fluids are drawn into the other one of the nozzle passage or the intake section for subsequent mixing of the working fluid and the produced fluid in the mixing section. In this manner both the working and produced fluids are accelerated before entering the mixing section to increase pump efficiency.

Abstract: Compositions and methods for the treatment of siliceous materials (e.g., silica and/or other silicates) in subterranean applications. Certain of those methods herein include providing a treatment composition comprising a base fluid, a catechol component, and an amine component; introducing the treatment composition into at least a portion of a subterranean formation comprising one or more siliceous materials; and allowing at least a portion of the treatment composition to contact at least a portion of the siliceous materials in the subterranean formation to dissolve at least a portion of the siliceous materials.

Abstract: The present invention relates to a scavenging composition capable of scavenging a wide variety of sulfur-bearing compounds, such as hydrogen sulfide and method of use thereof. Said scavenging composition comprises an aqueous solution of a triazine compound, an anionic surfactant, and optionally an alcohol and/or glycol ether solution. The composition may be used in any kind of sulfide-scavenging operation and is particularly useful for sulfide scavenging in the context of sulfide removal from oil or gas streams and in the treatment of oil or gas transmission lines or equipment.

Abstract: A downhole motor having a motor section, a drive shaft section, and an output shaft section. The output shaft section has a rotatable output shaft with a first end and a second end. A first thrust bearing assembly proximal to the first end of the output shaft, a second thrust bearing assembly proximal to second end to said output shaft. A radial bearing assembly disposed between the first and second thrust bearing assemblies.

Abstract: Methods and systems for automatically performing a sweep operation in a borehole penetrating an earth formation including conveying a drillstring through a borehole, the drillstring having one or more sensors located thereon, determining that a sweep operation should be performed based on information obtained from the one or more sensors, determining characteristics of a pill to be used for a sweep operation based on information obtained from the one or more sensors, preparing a pill in accordance with the determined characteristics, deploying the pill into the drillstring and conveying the pill through the drillstring, and monitoring the sweep operation while the pill is within the drillstring and verifying the sweep operation. At least one of the determination that a sweep operation should be performed, the determination of the pill characteristics, or the preparation of the pill is performed automatically.

Abstract: A method of treating a portion of wellbore comprising introducing a treatment fluid into the portion of the wellbore. The treatment fluid comprises a base fluid and an additive comprising a plurality of fibrillated fibers. The amount of fibrillation is at least sufficient such that at least a portion of the fibrillated fibers form a fiber network in the base fluid.

Abstract: A fracturing valve comprising a tubular mandrel having a through bore continuous with a tubing string, and a frac window through the side of the tubular mandrel. An outer sleeve is radially disposed around the tubular mandrel. The outer sleeve includes a sleeve port in a sidewall. The tubular mandrel slides relative to the sleeve by application and release of set down weight on a coiled tubing string. When the valve is closed, there is no fluid communication from the tubing string out of the frac window. When the valve is open, fluid communication from the tubing string is enabled. The valve may be installed in a downhole tool having a perforation device. The tool string can be used with one sealing element as the tool is pulled up the hole isolating lower perforations, or with two sealing elements to allow pin-point treatments isolating perforations both up and downhole.

Abstract: Lipophilic fibers are effective media for cleaning non-aqueous fluids out of a subterranean wellbore. The fibers are preferably added to a drilling fluid, a spacer fluid, a chemical wash, a cement slurry or combinations thereof. Non-aqueous fluids, such as an oil-base mud or a water-in-oil emulsion mud, are attracted to the fibers as they circulate in the wellbore.

Abstract: Methods include the injection of a gelled, gelling or gellable composition into a horizontal section of a well at a location, where produced well gases or a combination of well gases and injected gases are sufficient to move the pill through the horizontal section into heal section, sweeping the horizontal section of accumulated liquids. Once in the heal section, the pill and the accumulated liquids are uplifted to the surface resulting in a cleaned well.

Abstract: A rotary fluid drive has first and second bodies 20, 120. The second body 120 is rotatable relative to and inside of the first body 20 defining a working fluid space 40 there between. Gates 130 are supported by the first body 20 and lobes 124 are provide on the second body 120. Gate pockets 26 are formed in the first body 20 into which the gates swing when contacted by the lobes 124. The gates 130 and the gate pockets 26 are configured to form a debris chamber 27 there between capable of temporarily accommodating solid debris. Each gate 130 has a plurality of projections 136A with intervening gaps 136B. The gaps form a gate pocket flow path 141. Working fluid flows via each gate pocket flow path 141 into the working fluid space 40 when the associated gate 130 is maximally deflected into its associated gate pocket 26.

Abstract: A system to clean a tubular member includes an apparatus to support a tubular member having a bore with a longitudinal axis extending therethrough, and a fluid dispensing system disposed adjacent to an opening of the apparatus, the fluid dispensing system having a nozzle to dispense fluid therefrom.

Abstract: A carrier for at least one shaped charge, the carrier being disposable in use within an oil, gas, water or steam well bore. The carrier comprises a housing at least partially formed from a composite material which is non-frangible in normal use. The composite material component of the housing is arranged substantially to contain debris created within the carrier as a result of firing of the at least one shaped charge. The housing may be entirely of composite material or may comprise in inner metallic housing and an outer overwrap of composite material.

Abstract: Method to modify an existing subsea arranged oil production well having installed a hydraulically operated downhole valve, characterized in using coiled tubing technology to: arrange an electrically operated downhole pump in the production tubing, lock the hydraulically operated downhole valve in an open position by placing a sleeve body in the open positioned valve, arrange an electrically operated downhole valve above the downhole pump. A modified oil production well.

Abstract: A method of simultaneously stimulating at least a first and second zone of a subterranean formation that includes flowing a fluid through multiple flow rate restrictors, with a first restrictor located adjacent the first zone, a second restrictor located adjacent the second zone, and the first and second restrictors are connected in parallel. As at least one of the fluid properties changes, the flow rates of the fluid exiting the first and second restrictors are similar within a flow rate range, and allowing the fluid to stimulate at least the first and second zones. As at least one of the properties of the fluid changes, the pressure differential between a fluid inlet and a fluid outlet increases and as the pressure differential increases, the flow rate of the fluid exiting the fluid outlet is maintained within the flow rate range.

Abstract: A scalping insert includes a scalping surface having a plurality of scalping slots therethrough, and a vertical base portion. A shaker screen assembly includes a screen frame having at least one slot, and at least one scalping insert disposed in the at least one slot of the screen frame. A method of processing fluid includes providing a flow of fluid to a shaker screen assembly; and flowing the fluid through a scalping surface and a screen surface of a single shaker screen deck.

Abstract: A system for use with a subterranean well can include a fluid oscillator which discharges pulsating fluid from a tubular string in a direction at least partially toward an end of the tubular string proximate a surface of the earth. A method can include discharging a fluid from the tubular string, thereby applying a reaction force to the tubular string, which reaction force biases the tubular string at least partially into the well. Another method can include discharging a pulsating fluid from a fluid oscillator in a direction at least partially toward an end of the tubular string, and drilling into an earth formation with a drill bit connected at an opposite end of the tubular string in the well.

Abstract: A downhole tool for removing debris from a wellbore comprises a body having a bore, a collection member, and a means for creating a hydraulic barrier within a wellbore annulus. The hydraulic barrier within the wellbore annulus restricts upward movement of a debris laden fluid within the wellbore annulus causing the debris laden fluid to be directed toward the collection member. Thus, the hydraulic barrier facilitates removal of debris from the wellbore.

Abstract: The invention provides formulations for facilitating the removal of oil from a surface using a chisel composition, wherein the chisel composition includes a polymer having one or more binding points with a high affinity for the surface, and one or more hydrophilic segments that form a hydrophilic coating on the surface, rendering the surface water-wet and thereby facilitating the removal of oil from the surface. The invention also provides for methods of use of such formulations.

Abstract: A flow control apparatus for use in a wellbore comprises a screen, a first inflow control device and a second inflow control device, wherein a fluid inflow path is provided through the screen and from an outer portion to an inner portion of each inflow control device. A method of cleaning a flow control apparatus such as that described above comprises providing in a wellbore a flow control apparatus comprising at least one screen and at least one inflow control device wherein a fluid inflow path is provided through the at least one screen and from an outer portion to an inner portion of the at least one inflow control device, targeting the at least one inflow control device with a treatment fluid and delivering the treatment fluid such that the fluid flows in a reverse direction along the fluid inflow path.

Abstract: The present invention provides systems and methods for protecting the lower main wellbore of whipstocks and completion deflectors from debris accumulation. A well system subassembly includes a deflector tool arranged within a casing string and defining a deflector surface and an inner bore extending longitudinally from the deflector surface and one or more seal stacks disposed about the inner bore of the deflector tool. A wellbore barrier device is disposed about the inner bore uphole from the one or more seal stacks and is expandable from an unswelled configuration to a swelled configuration. When the wellbore barrier device is in the swelled configuration, it protects the one or more seal stacks from debris generated from milling and/or drilling operations.

Abstract: A fluid composition for cleanout of wellbores and pipe systems includes an effective amount of an amphiphilic chemical combined with an effective amount of a friction reducer in an aqueous solution of a base liquid. A remainder of the composition includes the base liquid.

Abstract: Apparatus (100) for use in top filling of tubulars comprising an inlet (200) for fluid communication with a top drive for providing top filling fluid, and an outlet (300) for fluid communication with a tubular. The apparatus (100) comprises a filter configuration (120), in fluid communication with the inlet (200) and the outlet (300) and configured to remove debris from a top filling fluid flow flowing from the inlet (200) to the outlet (300) during top filling of a tubular.

Abstract: A wellbore chemical treating system include a storage vessel for containing a treating chemical. A chemical dispenser is in fluid communication between an outlet of the vessel and a well for selectively controlling the flow of the chemical from the vessel to the well. A liquid level sensor is disposed in the storage vessel. A controller is in signal communication with the liquid level sensor and is configured to operate the chemical dispenser. The controller is configured to adjust an operating time of the chemical dispenser based on changes in a liquid level measured by the liquid level sensor over a selected period of time.

Abstract: Methods of performing a cleanout treatment including providing a wellbore in a subterranean formation having unconsolidated particulates therein; providing a treatment fluid comprising an aqueous base fluid and a hydrophobically modified flocculating water-soluble polymer; introducing the treatment fluid into the wellbore in the subterranean formation; flocculating at least a portion of the unconsolidated particulates by exposure to the hydrophobically modified flocculating water-soluble polymer; removing the treatment fluid comprising the flocculated unconsolidated particulates from the wellbore in the subterranean formation.

Abstract: Trivalent-ion chelating agents may be useful in mitigating the formation aluminum and ferric precipitates in subterranean formations during acidizing operations. An acidizing operation may include introducing an acidizing fluid into a wellbore penetrating a subterranean formation, the acidizing fluid comprising an aqueous fluid, an acid source, and a trivalent-ion chelating agent, e.g., hydroxamates, 6,7-dihydroxyquinoline, 3-hydroxy-4-pyridinones, and any combination thereof. In some instances, trivalent-ion chelating agents with a pKa of less than about 7 may be particularly useful in acidizing operations.

Abstract: An embodiment of the present invention includes a method comprising: (a) providing a filter cake on a surface in a subterranean formation, the filter cake comprising a polymer and a bridging agent; (b) providing a filter cake clean-up fluid that comprises an aqueous fluid and L-glutamic acid N,N-diacetic acid; and (c) contacting the filter cake with the filter cake clean-up fluid so that a portion of the subterranean formation neighboring the filter cake has a regain permeability of at least about 86%.

Abstract: A wellbore fluid for dissolving a filtercake includes a chelating agent and an aqueous solution of carboxylate salt. The concentration of the chelating agent is up to 50 percent volume per volume (v/v) in the aqueous solution of carboxylate salt. A method of treating a well includes preparing a wellbore fluid up to 50 percent volume per volume (v/v) chelating agent in an aqueous solution of carboxylate salt. The method further includes emplacing the wellbore fluid downhole such that the wellbore fluid dissolves a filtercake in the well.

Abstract: A jet pump and method of using the jet pump for removing fluids and solids from a conduit. The jet pump is adapted for use with a spoolable multi-string tubing system. The jet pump may be deployed rapidly and is suitable for temporary installation. The method may be used to reestablish flow in watered out and sanded off wells, or to test wells. The jet pump is adapted to remove wellbore fluid, which may be removed in combination with power fluid. The spoolable multi-string tubing system includes two or more substantially parallel conduits, allowing power fluid and return fluid to flow in separate conduits. Preferred embodiments provide additional functionality by inclusion of jetting elements, sensing elements, back-pressure valves, and auxiliary tubing strings or communication members in the spoolable multi-string tubing system.

Abstract: A well tool (100) for use in cleaning a well of fluids and debris characterized by one or more wiper elements (30) for swabbing the wellbore and internal passageways (11, 15) and valves (70, 72) in the tool, permitting forward and reverse fluid circulation through the tool to bypass the wiper elements.

Abstract: The present disclosure provides methods and compositions for scrubbing debris from a bored well and includes injecting a suspension of acrylonitrile fibers, into the bored well to its open end. The suspension of acrylonitrile fibers scrubs the bored well of loose debris without substantially impeding the drilling capability of the rig by raising the effective liquid viscosity in the bored well. Also provided are pre-measured form factors of the acrylonitrile fibers for convenient and precise preparation of the acrylonitrile fiber suspension at the bored well site.

Abstract: A downhole debris recovery tool including a ported sub coupled to a debris sub, a suction tube disposed in the debris sub, at least one magnet disposed in the debris removal tool, and an annular jet pump sub disposed in the ported sub and fluidly connected to the suction tube. A method of removing debris from a wellbore including the steps of lowering a downhole debris removal tool into the wellbore, flowing a fluid through a bore of an annular jet pump sub, jetting the fluid from the annular jet pump sub into a mixing tube, displacing an initially static fluid in the mixing tube through a diffuser, thereby creating a vacuum effect in a suction tube to draw a debris-laden fluid into the tool, flowing the debris-laden fluid past at least one magnet disposed in a debris housing, and removing the tool from the wellbore is also disclosed.

Abstract: Formulation for a natural product as a replacement for the use of traditional acidic chemical stimulation methods for the emulsification, removal and release of paraffin and asphaltenes from low producing or pumped off wells and reservoirs with the use of traditional methodologies. Also a method of use of formulation for stimulating an oil well consisting of introducing into the wellbore a biodegradable, non-reactive fluid system containing a water-miscible fatty acid solvent, a solution of fatty acids, an amino alcohol, and at least one non-ionic surfactant. The fluid system may be further in the form of a nanoemulsion that is formed by combining a colloidal solution with one or more emulsifiers, an alcohol, and water. The fluid system may be used in well remediation and stimulation as well as additional, alternative applications such as the cleaning of surface and/or downhole equipment.

Abstract: A wellbore fluid that includes an aqueous base fluid; a chelating agent; and at least one enzyme, wherein the wellbore fluid has a pH of at least 6.5 is disclosed.

Abstract: The present invention relates to an emulsion, consisting of an oil phase and an aqueous phase and comprising as emulsion components (?1) 15 to 40% by weight of at least one water-immiscible organic solvent as solvent of the oil phase, (?2) 15 to 40% by weight of water as solvent of the aqueous phase, (?3) 10 to 40% by weight of at least one surfactant, (?4) 10 to 40% by weight of an alkoxylated fatty alcohol and (?5) 0 to 25% by weight of at least one other additive, wherein the quantities by weight of the components (?1) to (?5) are each relative to the total weight of the emulsion, and together add up to 100% by weight. The invention further relates to a method for producing an emulsion, to the emulsion which can be obtained from said method, to the use of an emulsion, to a method for cleaning the surfaces of well holes, drilling devices or drillings, to a method for producing a well bore, and to a method for producing an oil or a gas.

Abstract: Wellbore-cleaning compositions comprising microemulsions are useful during cementing operations. The microemulsion solvent may be selected from the group comprising methyl esters and ethoxylated alcohols. The microemulsion surfactants comprise a water-wetting surfactant, a cleaning surfactant, an emulsifying surfactant, a non-ionic surfactant and a non-ionic co-surfactant. The wellbore-cleaning compositions may be pumped alone, ahead of a conventional spacer fluid or scavenger slurry and behind a conventional spacer fluid or scavenger slurry. In addition, the wellbore-cleaning composition may be incorporated into a carrier fluid such as (but not limited to) a conventional spacer fluid or scavenger slurry. The resulting fluid mixture may be pumped as a spacer fluid.

Abstract: Proppants for use in fractured or gravel packed/frac packed oil and gas wells are provided with a contaminant removal component to remove one or more of the contaminants found in subterranean water/hydrocarbon from a production well. The water/hydrocarbon cleaning proppant solids may be used as discrete particles in a proppant formulation, as a coating on proppant solids in pores of a porous proppant solid or as part of the proppant's internal structure. The contaminant removal component removes contaminants, especially dissolved contaminants, in the subterranean water or hydrocarbon before the water/hydrocarbon leaves the well. For those contaminant removal components that can be regenerated, such as ion exchange resins, a measured quantity of an acidic regeneration solution can be injected into the fractured stratum for regeneration and recovered when the well resumes production.

Abstract: A method of foaming a fluid for recovering gas from a gas well and enhancing oil production from a gas-lifted oil well penetrating a subterranean oil-bearing formation is disclosed and claimed. The method includes introducing into the fluid a foam-forming amount of a composition comprising at least one compound having the general formula: R1 is selected from a saturated linear or branched alkyl, an unsaturated linear or branched alkyl, a substituted naphthalene, a substituted benzene, a natural oil, and a natural oil derivative. R2 is a C2-C8 alkyl. R3, R4, and R5 are independently selected from trimethyl, triethyl, diethyl, monoethyl, benzyl dimethyl, and benzyl diethyl. X is selected from hydrogen, methyl, and ethyl. Z? is a negatively charged counterion.

Abstract: Treatment fluids may be used to retard the deposition of silica scale in subterranean formations. Methods for treating a subterranean formation can comprise providing a treatment fluid having a pH of 6 or less that comprises an acidic base fluid and a non-polymeric silica scale control additive, and introducing the treatment fluid into at least a portion of a subterranean formation. The non-polymeric silica scale control additive retards deposition of silica scale in the subterranean formation.

Abstract: The debris collection device operates on an eductor principle with motive fluid delivered from the surface into an eductor housing inlet. The eductor outlet goes into a surrounding annular space and splits with some flow going to the mill below to direct cuttings into the passage in the housing. The cuttings remain in the housing and the flow continues through a screen in the housing passage before reaching the eductor inlet. An auxiliary inlet is normally closed and opened with a reduced flow entering through the mill. The opening of the auxiliary inlet drops the surface pressure delivered to the eductor to act as a surface signal that a plugged or low debris laden inlet flow exists.

Abstract: Methods for remediating a subterranean formation can comprise: introducing a first remedial fluid into a first portion of a subterranean formation, wherein the first remedial fluid comprises a base fluid and a viscosifying agent; and allowing the first remedial fluid to divert at least a portion of a second remedial fluid that comprises an oxidizer to a second portion of the subterranean formation; wherein the viscosifying agent comprises at least one viscosifying agent selected from the group consisting of a gelling agent, an emulsifier, or a gas in combination with a foaming agent; and wherein the gelling agent, if present, comprises at least one polymer selected from the group consisting of xanthan, diutans, wellans, succinoglycan, clarified biopolymers, scleroglycan, combinations thereof, and derivatives thereof.

Abstract: Compositions for chemically removing sulfur deposits from reservoir formations, production tubing, flow lines, and other production equipment due to the production of sour gas and/or oil including reaction products of diamines and aldehydes at a mole ratio between about 1:1 and about 1:6, and methods for making and using same.

Abstract: The present invention relates to a method of removing and preventing water and condensate blocks in wells by contacting a subterranean formation with a composition comprising a low molecular weight fluorinated copolymer having perfluoro alkyl moieties which are no longer than C6. A fluorinated copolymer of low molecular weight of about 50,000 g/mol and a method of preparing the same are also disclosed.

Abstract: Acidic fluids used in wells or pipelines cause corrosion of carbon steel. Methods for inhibiting corrosion include contacting carbon steel with a fluid having an aqueous acidic phase including a material selected from the group consisting of: a material of a plant in the Solanaceae family, an extract of a material of a plant in the Solanaceae family, a withanolide, a source of a withanolide, a withanolide derivative, a source of a withanolide derivative, and any combination thereof. The methods have wide application in various kinds of operations involved in the production or transportation of oil and gas, such as acid stimulation in a well or remedial treatment in a pipeline.

Abstract: Disclosed is a two-stage filter cake removal composition, and method of use thereof, for use in a wellbore for controlled removal of a filter cake present in a target production zone. The two-stage filter cake removal composition may include an enzyme present in an amount of between about 1% and 10%, and a glycolic acid in amounts of between about 1% and 10% by weight. Optionally, hydrochloric acid may be added to the glycolic acid, in an amount of about 1 and 5% by weight. The two-stage filter cake removal composition, when the enzyme is applied to the filter cake in the target production zone in a first stage and the glycolic acid is applied to the filter cake in the target production zone in a second stage, is operable to remove the filter cake in the target production zone over a predetermined extended reaction time.