Abstract: A process for fracturing a subterraneous formation in the production of an oil well is described. The process steps include injecting an initial charge of a mixture, the mixture being formed from at least a water-insoluble adsorbent and at least one well treatment agent, into a well bore formed in the subterraneous formation so as to form a downhole matrix within the formation; injecting a solution comprised of an additional amount of the well treatment agent into the formation after the initial charge of the at least one well treatment agent has been substantially depleted; and then pressurizing the well bore for a time and under conditions sufficient to reactivate the downhole matrix in the formation, so that the treatment agent activity of the matrix is increased relative to the treatment agent activity of the matrix just prior to injecting the solution.

Abstract: A microemulsion delivery system containing a well treatment agent in a water-in-oil microemulsion may be used for well remediation as well as in other treatment operations including stimulation, acidizing, and drilling. In addition, the water-in-oil microemulsion delivery system may be used to clean surface equipment and downhole equipment.

Abstract: A method for wellbore treatment includes running a liner into a wellbore, the liner including a wall, an inner bore defined by the wall, a first port through the wall, a second port though the wall spaced axially from the first port, a first removable closure for the first port and a second removable closure for the second port; positioning the liner in an open hole section of the wellbore to create an annulus between the liner and a portion of the wellbore wall and with the second port downhole of the first port; inserting a treatment string assembly into the liner, the treatment string assembly including a tubing string and an annular seal about the tubing string and being insertable into the inner bore of the liner; setting the annular seal to create a seal between the tubing string and the liner downhole of the second port; and while the first port is closed to fluid flow therethrough, pumping wellbore treatment fluid into an annular area between the tubing string and the liner such that the fluid passes

Abstract: A method of treating a downhole region penetrated by a wellbore with a treatment agent is given, including delivering the treatment agent to the wellsite enclosed in one or more destructible containers, inserting the one or more destructible containers into the fluid being pumped down the well, and mechanically breaking the one or more destructible containers in the wellbore or in the formation to release the treatment agent. A method is also given for treating a downhole region penetrated by a wellbore with a special solid diverting material, which includes special shapes such as fibers or flakes and/or blends of specially sized particles, including delivering the special solid diverting material to the wellsite enclosed in one or more containers, inserting the one or more containers into fluid being pumped down the well, and allowing the one or more containers to release the special solid diverting material in the wellbore.

Abstract: A method includes treating a first formation intersecting a wellbore, preparing a diversion fluid including an inactivated viscosifier and an inactivated thinning agent, and positioning an amount of the diversion fluid to isolate the first formation. The method further includes delivering an activator to the diversion fluid, thereby activating the inactivated viscosifier and triggering a thinning agent activation process. The method further includes treating a second formation intersecting the wellbore. The method further includes providing a residence time until the thinning agent activation process completes and the thinning agent breaks the viscosified diversion fluid. The method further includes flowing fluid back from the first formation and the second formation.

Abstract: A method of treating crude oil which comprises contacting the oil with a treatment fluid formulation comprising a polymeric material which comprises vinylalcohol repeat units, wherein said polymeric material is of a type which has a weight average molecular weight in the range 5,000 to 50,000 and/or wherein the viscosity of a 4 wt % aqueous solution of the polymeric material at 2° C. is in the range 1.5-7 cP. The oil may be contacted with the treatment fluid formulation underground by, for example, injection of the fluid formulation into an injection well or production well and the mobility of the oil contacted thereby is significantly improved.

Abstract: Methods of treating a subterranean formation comprising first introducing a pre-flush fluid into a subterranean formation having particulate matter therein. Then introducing a curable adhesive composition comprising a silane coupling agent and a polymer, the polymer having a reactive silicon end group into the subterranean formation subsequent to the pre-flush fluid. Then introducing an aqueous post-fluid fluid into the subterranean formation subsequent to the curable adhesive composition. Then allowing the curable adhesive composition to at least partially consolidate particulate matter within the subterranean formation.

Abstract: A method involving exposing a substance to a promoter, the promoter being made from a liquid carrier and a metal salt component, the metal salt component, having at least (i) a magnetic susceptability above 1000 or (ii) an ionization potential below about 500 volts, or (iii) both (i) and (ii), and applying electromagnetic wave energy to the substance while the substance is in the presence of the promoter, for a period of time and at a frequency and amplification sufficient to promote the modification of at least one physical property of the substance. A related method of treating a well in a subterranean formation, a tank or a pipeline, and the well treatment promoter composition, are also described.

Abstract: A method for reducing the friction forces between tubulars, for example coiled tubing in casing, is disclosed. The method includes mixing a selected surfactant and particles of TEFLON in oil, then adding the oil to water and pumping the mixture down the tubing. The mixture is particularly useful in coiled tubular drilling inside casing. The formulation has also been found to reduce corrosion on metal surfaces.

Abstract: Liquid loading, corrosion and scaling in an oilfield tubular, such as a production tubing in a natural gas production well, is inhibited by treating the inner surface of the oilfield tubular (4,24) with a hydrophobic or other coating or lining which inhibits creation of a liquid film and promotes liquid droplet flow alongside said inner surface.

Abstract: The method comprises deploying through a well a substantially longitudinal body comprising at least in part a degradable material able to release a chemical; positioning the longitudinal body at a downhole location from the well; and allowing the degradable material to degrade and the chemical to be released.

Abstract: In one aspect, the invention is directed to polypeptides having an amylase activity, polynucleotides encoding the polypeptides, and methods for making and using these polynucleotides and polypeptides. In one aspect, the polypeptides of the invention can be used as amylases, for example, alpha amylases, to catalyze the hydrolysis of starch into sugars. In one aspect, the invention provides delayed release compositions comprising a desired ingredient coated by a latex polymer coating.

Abstract: A method of mitigating corrosion of downhole articles includes mixing a plurality of nanoparticles into a first downhole fluid to form a nanoparticle fluid. The method also includes exposing a surface of a downhole article in a wellbore to the nanoparticle fluid. The method further includes disposing a barrier layer comprising a portion of the nanoparticles on the surface of the article and exposing the surface of the downhole article to a second downhole fluid, wherein the barrier layer is disposed between the second downhole fluid and the surface of the article.

Abstract: Lost circulation of drilling fluid is one of the most serious and expensive problems facing the drilling industry. The present invention relates to an improved drilling fluid for reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well. The drilling fluid comprises a base fluid and wax or waxy substance as a primary seepage loss agent. In a particularly preferred embodiment, the seepage loss agent does not include particles having a blend of natural wax and synthetic wax together in a single particle. The invention also provides a method of reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well using the drilling fluid of the invention, wherein the primary seepage loss agent is added to the drilling fluid, either before or during drilling, and the drilling fluid is pumped down hole during drilling.

Abstract: A method can include applying a magnetic field to a well screen, thereby varying sizes of pores via which fluid flows through the well screen. A well screen can include a magnetic shape memory material having a dimension which changes in response to application of a magnetic field. Restriction to flow through the well screen can vary in response to the change in dimension of the magnetic shape memory material.

Abstract: The present invention is related in general to fluid compositions and methods for servicing subterranean wells. Particularly, the invention relates to the use of a fiber-laden fluid to separate two wellbore-service fluids as they travel through a tubular body, preventing their commingling. The invention obviates the need for mechanical devices such as wiper plugs, or special adjustment of the wellbore-service fluids' rheological properties.

Abstract: A method can include introducing a particulate diverting agent into a first fracture within an underground reservoir formation. The particulate diverting agent can at least partially hydraulically isolate the first fracture. The particulate diverting agent can also be a temporary material which substantially degrades over an extended time. The underground reservoir formation can be stimulated with a stimulation fluid sufficient to expand a second fracture within the underground reservoir formation. The particulate diverting agent can then be allowed to substantially degrade.

Abstract: Methods of creating degradable particulates in a subterranean environment. The methods provide a degradable material supercritical fluid mixture that comprises degradable material into a wellbore penetrating a subterranean formation and provide an orifice between the wellbore and the subterranean formation wherein the pressure in the subterranean formation is less than the pressure in the wellbore. The degradable material supercritical fluid is then fed through the orifice into the subterranean formation such that the degradable material supercritical fluid mixture expands through an orifice into the lower subterranean formation and particulates are formed.

Abstract: Method of diverting fluids in a subterranean formation including the steps of providing a first fluid comprising an aqueous fluid and a hydrophobically modified water-soluble relative permeability modifier; introducing the first fluid into a well bore such that the first treatment fluid penetrates into a portion of the subterranean formation in a sufficient amount so as to substantially divert a second treatment fluid to another portion of the subterranean formation. Then, a second aqueous fluid is introduced into the well bore and substantially diverted from the portion of the subterranean formation penetrated with the first treatment fluid. In some cases, a well treatment operation, such as acid stimulation operation, a clay stabilization operation, or a scale inhibition operation, is performed using the second fluid.

Abstract: In some embodiments, apparatus useful for providing fluids or equipment into a subterranean well through a production tubing and associated dead string includes an injection system that is movable into and out of the well without removing the production tubing. The injection system includes a stopper that forms the seal that creates the dead string.

Abstract: Methods for scale inhibition treatment of oil or gas production wells generally include injecting a scale inhibition composition into the oil or gas production well, wherein the scale inhibition composition comprises one or more polymers, each polymer comprising recurring units of a first monomer and a second monomer, wherein: (i) the first monomer is selected from maleic acid, maleic anhydride, fumaric acid, acrylic acid, salts thereof, or combinations thereof; and (ii) the second monomer is selected from vinyl sulfonic acid, allyl sulfonic acid, methallylsulfonic acid, salts thereof, or combinations thereof; wherein the concentration of the polymers in the composition is about 10 to about 60 percent of the polymers by weight of the composition; and wherein the composition has a pH of about 7 to about 8.5.

Abstract: The disclosed compositions and methods utilize hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups. The polymers may exhibit physical association in solution at a specific temperature so as to provide a significant increase in viscosity at the specific temperature. The viscosity of such systems is substantially increased by the further inclusion of one or more hydrophilic components that may exhibit physical association in solution at one or more temperature trigger points and also associate with the one or more hydrophilic polymers modified by the incorporation of one or more hydrophilic side groups.

Abstract: An apparatus, system and method for delivering a mixture of well treatment chemicals into a well are disclosed. A chemical distribution device includes mixing manifold that receives well treatment chemicals and solvent that are to be mixed. A siphon is positioned within the mixing manifold to control the fluid level. The mixture is not delivered from the chemical distribution device until the fluid level of the mixture is above a crest of the siphon. The mixture is delivered in a batch to the well via a flowline until the fluid level of the mixture is below the inlet of the siphon.

Abstract: A method to enhance oil recovery from a subterranean reservoir, the reservoir being accessible via a production well. The method includes injecting a surfactant solution that includes surfactants into the production well. The surfactant solution selected to increase an oil-to-water ratio of oil recovery from a porous matrix portion of the reservoir. The method also includes injecting a well-servicing volumetric solution into the production well to perform a second well treatment process. The second well treatment process is selected from the group consisting of a scale inhibition squeeze process, a well acidizing process, a chemical process to reduce water production rate, an acid fracturing process, and a hydraulic fracturing process. In the method, the surfactant solution and the second well treatment solution are injected into the production well within less than about six months of one another.

Abstract: Systems and methods of treating a gas stream are described. A method of treating a gas stream includes cryogenically separating a first gas stream to form a second gas stream and a third stream. The third stream is cryogenically contacted with a carbon dioxide stream to form a fourth and fifth stream. A majority of the second gas stream includes methane and/or molecular hydrogen. A majority of the third stream includes one or more carbon oxides, hydrocarbons having a carbon number of at least 2, one or more sulfur compounds, or mixtures thereof. A majority of the fourth stream includes one or more of the carbon oxides and hydrocarbons having a carbon number of at least 2. A majority of the fifth stream includes hydrocarbons having a carbon number of at least 3 and one or more of the sulfur compounds.

Abstract: Methods of treating subterranean formations to reduce bacteria load are provided. Some methods include the steps of providing a treatment fluid, particulates, and tri-n-butyl tetradecyl phosphonium chloride (TTPC) wherein the TTPC is in liquid form or in solution; coating the TTPC onto the particulates; combining the particulates coated with TTPC with the treatment fluid to create a suspension; and, placing the suspension into the portion of the subterranean formation. Other methods involve the use of TTPC in the form of a solid salt.

Abstract: The invention relates to providing controlled delivery of subterranean fluid additives to a well bore treatment fluid and/or a surrounding subterranean environment using intelligent materials that respond to a magnetic stimulus to release subterranean fluid additives downhole in a subterranean environment. Methods disclosed include a method of releasing a subterranean fluid additive in a subterranean formation comprising: providing a magnetically-sensitive component that comprises a subterranean fluid additive; providing a magnetic source; and releasing the subterranean fluid additive in the subterranean formation from the magnetically-sensitive component using a magnetic force generated from the magnetic source.

Abstract: This invention relates to oil and gas production, more specifically, to the methods of producing polymer emulsion for downhole operations and mixing degradable (hydrolysable) polymer emulsion with the treatment fluid.

Abstract: A process is presented for selecting a treatment option for enhancing oil recovery from a geological formation in a remote location. The process includes a selection process for identifying a suitable treatment option.

Abstract: The present application describes improved compositions for wellbore fluids for use in downhole (e.g. oilwell) applications. The compositions comprise a blocked isocyanate (BI) component having a tolerance improving group (such as a hydrophilic group, e.g. an amine) bonded to it, and an active hydrogen component. When the BI group is unblocked, it reacts with the active hydrogen component to form a gel which, by virtue of the tolerance improving group, is more tolerant to contaminants (such as aqueous inorganic salts or brines) than the corresponding gel forms from unmodified BI. The application also relates to methods of treating an earthen formation using such a composition.

Abstract: The present invention provides thermoplastic coated proppants and methods for preparing the thermoplastic coated proppants. Methods for using these proppants in subterranean well formations and hydraulic fracturing operations, for example, are also disclosed.

Abstract: A wellbore fluid is an aqueous carrier liquid with first and second hydrophobic particulate materials suspended therein. The first hydrophobic particles have a higher specific gravity than the second hydrophobic particles and the fluid also comprises a gas to wet the surface of the particles and bind them together as agglomerates. The fluid may be a fracturing fluid or gravel packing fluid and the first particulate material may be proppant or gravel. The lighter second particulate material and the gas both reduce the density of the agglomerates which form so that they settle more slowly from the fluid, or are buoyant and do not settle. This facilitates transport and placement in a hydraulic fracture or gravel pack. One application of this is when fracturing a gas-shale with slickwater. The benefit of reduced settling is better placement of proppant so that a greater amount of the fracture is propped open.

Abstract: Disclosed herein are an acid emulsion fluid for use in sealing target portions of a hydrocarbon producing formation penetrated by a wellbore and the method of use thereof for fluid loss control.

Abstract: Shaped particulates which have been compressed from a composite of a well treatment agent and adsorbent in a matrix may be introduced into horizontal or deviated oil or gas wells. The well treatment agent of the shaped pellets may be used to prevent and/or control the formation of deposits in a production well.

Abstract: A method to improve the effectiveness of MEOR or bioremediation processes has been disclosed. In this method toxic chemicals accumulated in subterranean sites adjacent to the water injection wells are either dispersed or removed prior to introduction of microbial inocula for enhanced microbial oil recovery or bioremediation of these sites.

Abstract: A method of demulsifying a water-in-oil emulsion is provided. The method includes treating a volume of fluids comprising oil and water by adding a salt of a polynuclear, aromatic sulfonic acid to the fluids so as to cause the oil and water to be at least partially demulsified. The method may further include separating water and oil in a separator. A method of producing hydrocarbons from a subsurface reservoir is also provided. The hydrocarbons include a water-in-oil emulsion. The method includes producing the hydrocarbons through a wellbore, and subjecting the water-in-oil emulsion to a salt of a polynuclear, aromatic sulfonic acid additive so as to cause the oil and water to be at least partially demulsified.

Abstract: Disclosed are compositions and methods for providing fluid-loss control in subterranean wells. Well-completion fluids contain fine particulate additives whose glass-transition temperatures are below the anticipated bottomhole temperature. The particles soften upon injection into the well, whereupon they soften and become deformable. The particles then migrate to the borehole wall and form a seal that reduces further fluid flow from the borehole into the formation. The additive may be supplied as a powder or in the form of a liquid suspension.

Abstract: A method including exposing a substance to a first type of electromagnetic waves generated by a first device. The frequency of the first type of electromagnetic waves is in the radio frequency range and the device preferably consumes no more than about 1,000 Watts of power. The exposure takes place for a period of time and at a frequency sufficient to detectably alter at least one physical property of the substance as it existed prior to the exposure. The substance is selected from the group consisting of a hydrate, a water and oil emulsion, clay, scale, cement, a completion fluid, tank sediment and iron sulfide.

Abstract: In various embodiments, provided are materials and methods for controlling the flow of water, steam, drilling fluid, hydraulic stimulation fluid, hydrocarbon (oil or gas), or combinations thereof, in drilled wells (such as enhanced geothermal system wells, oil wells, or natural gas wells) by at least partially and temporarily obstructing one or more of a geologic fracture, perforation, or wellbore in a reversible manner.

Abstract: The technical challenges for a smooth transition between using both a thermodynamic hydrate inhibitor (THI) and a kinetic hydrate inhibitor (KHI) to simply using only the KHI in multiple tie-in gas natural gas production systems is solved by adding more THI in a first pipeline leg of the production system while ceasing adding THI in a second pipeline leg of the system. Further, more KHI is added into the second leg of the system, and subsequently THI is gradually and/or slowly reduced in the remaining legs of the system until only KHI is being injected, after which the KHI amount in all legs may be reduced to the equilibrium or steady-state levels.

Abstract: Disclosed is a method and system for controlling the formation of liquid or gas slugs along a pipeline. In embodiments, an injection unit injects a liquid surface tension reducing agent, such as a foamant, into the pipeline upstream of the high point. A control unit can be used to control the injection unit. In certain arrangements, the control unit adjusts the injection of the agent based on measured parameters of interest. In embodiments where the control unit utilizes temperature measurements, one or more temperature sensors are positioned along the pipeline. The control unit utilizes the temperature measurements to determine whether a predetermined condition exists or a liquid or gas slug is present.

Abstract: Treatments and compounds useful in subterranean formations are discussed, with particular attention to fracturing treatments where particulates and/or surfaces may be subject to water intrusion. Certain methods pertain to utilizing diagenesis source material to create porous structures in a subterranean formation. Such porous structures may be formed of consolidated particulates and/or diagenic product. Certain methods pertain to analyzing and/or quantifying the effects of the other methods disclosed herein.

Abstract: An apparatus and related methods for removing hazardous trace elements from hydrocarbon reservoir effluent is implemented by placing an adsorbing volume of material designed to adsorb the hazardous trace elements into the vicinity of a producing formation face at a downhole location; and letting the reservoir effluent flow through the volume of adsorbing material

Abstract: A method and apparatus for hydrocarbon recovery and/or treatment of frac water includes introducing a volume of water into a formation, recovering the introduced water, with the recovered introduced water further comprising suspended hydrocarbon product. The recovered liquid is treated to remove substantial amounts of the suspended hydrocarbon product, provide the treated recovered liquid with a ORP in a range of 150 mv to 1000 mv, and partially desalinated, and is either re-introduced as treated recovered liquid with the ORP into a formation to assist in recovery of additional hydrocarbon deposits in the formation, or is stored to reduce the ORP and then subsequently discharged into surface waters.

Abstract: A composition of matter and a method of sealing a permeable formation are provided incorporating the composition to reduce or eliminate lost circulation in permeable formations up to at least 6000 psi. The composition comprises one or more sealing components, a wetting component, a viscosifier component, an activator or flocculant component, and an extender. A dry mixture of the components may be added directly from the bag to the drilling mud up to the rate of 90 pounds per barrel. The mixture will seal the formation in an aqueous or organic environment. The mixture de-waters at a rapid rate without regard to the time and temperature required for curing agents or other additives. The mixture may be weighted and does not require additional agents such as defoamers, accelerators, retarders or spacers to de-water and set as a solid plug.

Abstract: The present invention is directed to an improved thermoplastic material-coated particulate composition useful for hydraulic fracturing treatments, gravel packing for sand control or other well formation treatments and especially the related methods of its use and is particularly directed to using a thermoplastic material as part of a particulate composition in a method for enhancing the stabilization of and reducing particulate flowback and fines transport in a well formation.

Abstract: In solvent-dominated recovery processes for recovering In situ oil, including bitumen, the produced fluid stream includes oil and solvent. The solvent is preferably recovered and reinjected into the reservoir. In previously described methods, solvent is removed from the oil/solvent mixture. In the present method, the oil/solvent mixture is first separated into a heavier stream and a lighter stream from which solvent is independently removed.

Abstract: Among many things, in some embodiments, improved viscoelastic surfactant gels that comprise non-aqueous tackifying agents, and their associated methods of use, are provided. In one embodiment, the methods comprise: providing a treatment fluid that comprises an aqueous base fluid, a non-aqueous tackifying agent, and a viscoelastic surfactant; and introducing the treatment fluid into a subterranean formation.

Abstract: An electric plasma arc apparatus and method produces nitrogen compounds, solely using ambient air extracted in proximity to the apparatus. The nitrogen compounds are brought into contact with a water processing system, forming nitrate on-site. Hydrogen sulfide present in the water processing system is removed, and the production of hydrogen sulfide by sulfate-reducing bacteria (SRB) is eliminated by introducing nitrate into the system, whereby denitrifying microorganisms, using the nitrate, outcompete the sulfate-reducing bacteria for the available carbon nutrients, thus preventing the SRB from producing hydrogen sulfide. Nitrate ions generated in the water processing system which contains the denitrifying microorganisms can enhance oil recovery by means of microbial enhanced oil recovery mechanisms.

Abstract: Improvement in the compatibility of hydrocarbon and water is achieved by surface active agents newly synthesized by mixed microbial populations. Methods for enhancing the microbial production of surface-active agents in hydrocarbon-exposed surface waters can be achieved by supplementing the mixed microbial population with one or more carbon sources, most notably propionate. Hydrocarbon-exposed surface waters having enhanced levels of surface-active agents can be used to improve hydrocarbon recovery from subterranean formations or for remediation of hydrocarbon-contaminated sites.