Abstract: Methods and compositions for use in subterranean operations, and more particularly, additives comprising one or more silicates used to treat tar resident in a well bore, and methods of use, are provided. In one embodiment, the method comprises a method of treating tar resident in a well bore comprising providing a tar-treating additive comprising one or more silicates introducing the tar-treating additive into the well bore; and allowing the tar-treating additive to react with the tar resident in the well bore so as to at least partially reduce the adhesiveness of the tar.

Abstract: A method to clean a wellbore and the near wellbore area adjacent to the wellbore of a hydrocarbon bearing and/or coal bed methane formation adjacent to the production zone of the wellbore is provided. Specifically, a method for removing liquids such as water and/or oil from the near wellbore formation is provided. Furthermore, A method to clean a casing inserted into a wellbore is also disclosed. A method for cleaning a wellbore of fracturing fluid, with or without proppant is also disclosed. Each of the methods includes the steps of injecting either liquid carbon dioxide or a treatment medium comprising liquid carbon dioxide into a wellbore through tubing such that the location at which the treatment medium is administered may be controlled. In some embodiments, pressure within the wellbore is regulated in order to either maintain the treatment medium in the liquid state, or allow at least a portion of the treatment medium to vaporize upon introduction into the wellbore.

Abstract: A downhole tool (10) for use in oil and/or gas well bores. The tool has a tubular body (20) and a sleeve (22) including stabilizer blades (30). The tool is ball (76), activated, weight activated or hydraulically activated to selectively jet fluid from the body through jetting ports (44A, 44B, 44C) on the blades. Thus the tool provides the features of a stabilizer, cleaning tool and circulation tool in-one.

Abstract: The present invention relates to a method of removing deposits from various types of wells (17) including environmental recovery, water supply, horizontal, barrier, injection, recharge, and/or disposal wells (17). The method includes equipping a well (17) with an automated energy delivering system that is attached to the well (17). The energy delivering system is used to clean the surface of the well (17) and aquifer by supplying various types of energy to the well (17) and aquifer via injection lines (5, 6, 11, 12 and 13) and an educator pipe (10). A pump (14) is used to pump the energy through flow valves (20 and 21) and injection lines (5, 6, 11, 12 and 13) and into the well (17). The energy that is supplied to the well (17) mobilizes any deposits in the well (17) and aquifer and cause them to flow into and up the wellbore thereby cleaning the well (17) and aquifer.

Abstract: A method and apparatus for substantially cleaning fill from a borehole is described variously including running a coiled tubing assembly into the wellbore, creating a fluid vortex by circulating cleaning fluid through the coiled tubing, and pulling the coiled tubing and coiled tubing assembly out of the hole at a speed sufficient to substantially clean the particulate solids from the wellbore. An apparatus for substantially cleaning fill from a hole, including vertical, horizontal, or deviated wells also is provided.

Abstract: Nanoemulsion, macroemulsions, miniemulsions, microemulsion systems with excess oil or water or both (Winsor I, II or III phase behavior) or single phase microemulsions (Winsor IV) improve the removal of filter cakes formed during hydrocarbon reservoir wellbore drilling with OBM. The macroemulsion, nanoemulsion, miniemulsion, microemulsion systems with excess oil or water or both or single phase microemulsion removes oil and solids from the deposited filter cake. In one non-limiting embodiment, the emulsion system (e.g. single phase microemulsion, nanoemulsion, or other emulsions) may be formed in situ (downhole) rather than produced or prepared in advance and pumped downhole. Skin damage removal from internal and external filter cake deposition can be reduced.

Abstract: An engine/steam generator which converts hydrogen peroxide to superheated steam and oxygen and having an afterburner that together with a reducing agent, utilizes the oxygen, thereby supplying oxygen free super-heated steam under pressure for oil well stimulation. Fluids such as water and KH30 can be injected into the engine/stem generator. The invention also relates to an apparatus and methods of incineration, soil remediation, land fill remediation, controlled vault burning, chemical atomization/vaporization, home heating, generation of electricity, diesel engine exhaust cleaning, steam turbine, gas path cleaner for jet engines, steam cleaning, natural gas engine power booster emission reducer, chemical storage tank cleaning, portable gas drive, and metal tempering.

Abstract: A method of treatment of subterranean formations in which leakoff through natural fractures is controlled through the use of fibers. The method involves pumping a mixture of a formation treatment fluid and a fiber into the formation for matrix stimulation, fracture stimulation, diversion, and/or water control. In carbonate formations, the formation treatment fluid is preferably an in situ gelled acid. The method optionally also involves pumping the same or a different formation treatment fluid without fiber.

Abstract: A device for use with components for a downhole tool—such as a throat, a nozzle, or a diffuser—used for cleaning a wellbore, are disclosed which decreases the erosion of the components. The device may be comprised of a hardened material, such as stack of pure diamond disks brazed to form an insert for a throat. The device may also be comprised of polycrystalline diamond (PCD) washers stacked together and mechanically secured within the component such as a throat. The device may also be comprised of diamond grown on a mandrel into a trumpet shape, which may then be brazed or epoxied into the component. As each of these materials is harder than materials previously utilized, erosion performance is enhanced. A method of improving erosion performance of components utilized to clean a wellbore is also disclosed.

Abstract: To perform a cleanout operation in a wellbore, a cleaning tool having a coiled tubing and an electrical pump assembly is run into the wellbore. The electrical pump assembly that is located in the wellbore is activated. In response to fluid flow generated by the electrical pump assembly, removal of debris from the wellbore is caused by directing fluid containing the debris into the coiled tubing for delivery to an earth surface.

Abstract: A scale dissolver fluid for dissolving scale in a subterranean hydrocarbon-bearing formation comprises an effective amount of a scale dissolver formulation and an effective amount of a surfactant for controlling the viscosity of the fluid. In use, formation hydrocarbons act on the surfactant to reduce the viscosity of the fluid so that the fluid selectively invades a hydrocarbon-bearing zone of the formation.

Abstract: The present invention relates to a method of removing deposits from various types of wells (17) including environmental recovery, water supply, horizontal, barrier, injection, recharge, and/or disposal wells (17). The method includes equipping a well (17) with an automated energy delivering system that is attached to the well (17). The energy delivering system is used to clean the surface of the well (17) and aquifer by supplying various types of energy to the well (17) and aquifer via injection lines (5, 6, 8, 11 and 12) and an educator pipe (10). A pump (14) is used to pump the energy through flow valves (21 and 20) and injection lines (5, 6, 8, 11 and 12) and into the well (17). The energy that is supplied to the well (17) mobilizes any deposits in the well (17) and aquifer and cause them to flow into and up the wellbore thereby cleaning the well (17) and aquifer.

Abstract: A method and composition for protecting cement surfaces in a well bore treatment zone from the destructive effects of acid mud and other acidization processes commonly used to stimulate hydrocarbon production from the formation, includes contacting the cement with an aqueous acid mixture of HAc and HF in a mutual solvent for a sufficient period of time to form a protective deposit or precipitate layer that is resistant to the acidization composition. In a preferred embodiment, the aqueous acid mixture includes corrosion inhibitors and inhibitor aids, and a preflush with an ammonium chloride solution in a mutual solvent is used to prepare the cement surfaces in the treatment zone.

Abstract: In some embodiments, a method of delivering at least one chemical into an underground well equipped with a reciprocating plunger includes retaining the plunger above the well after the well is unloaded and shut in, dispensing at least one chemical into the well and releasing the plunger so that the plunger may drop in the well after the chemical(s).

Abstract: Sulfonated graft copolymer obtained by radical graft copolymerization of one or more synthetic monomers in the presence of hydroxyl-containing naturally derived materials. The graft copolymer includes 0.1 to 100 wt %, based on weight of the total synthetic monomers, of at least one monoethylenically unsaturated monomer having a sulfonic acid group, monoethylenically unsaturated sulfuric acid ester or salt thereof, with the monomer and hydroxyl-containing naturally derived materials present in a weight ratio of 5:95 to 95:5.

Abstract: The present invention generally relates to a method for recovering productivity of an existing well. First, an assembly is inserted into a wellbore, the assembly includes a tubular member for transporting drilling fluid downhole and an under-reamer disposed at the end of the tubular member. Upon insertion of the assembly, an annulus is created between the assembly and the wellbore. Next, the assembly is positioned near a zone of interest and drilling fluid is pumped down the tubular member. The drilling fluid is used to create an underbalanced condition where a hydrostatic pressure in the annulus is below a zone of interest pressure. The under-reamer is activated to enlarge the wellbore diameter and remove a layer of skin for a predetermined length. During the under-reaming operation, the hydrostatic pressure is maintained below the zone of interest pressure, thereby allowing wellbore fluid to migrate up the annulus and out of the wellbore.

Abstract: The invention generally relates to a spacer system for cleaning a section of a subterranean well borehole and casing prior to cementing. The spacer system of the invention comprises a at least one alkyl ether citrate and, optionally, at least one alcohol ethoxylate.

Abstract: A method for extracting accumulated material from a well bore includes pressurizing gas recovered from the well bore and disposing an extraction string in communication with a sump. The sump is disposed to receive liquid from the well bore. The method further includes sealing the sump and injecting at least a portion of the pressurized gas into the sump such that at least some of the liquid in the sump is driven upward into the extraction string.

Abstract: The present invention relates to methods and compositions for use in subterranean operations. More particularly, the present invention relates to additives comprising one or more silicates used to treat tar resident in a well bore, and methods of use. In one embodiment, the present invention provides a method of treating tar resident in a well bore comprising providing a tar-treating additive comprising one or more silicates introducing the tar-treating additive into the well bore; and allowing the tar-treating additive to react with the tar resident in the well bore so as to at least partially reduce the adhesiveness of the tar.

Abstract: A technique that is usable with a well includes providing a sequencing valve to in a first state to communicate a first flow through a first port of the valve and in a second state close fluid communication through the first port. The technique includes communicating a second flow through an orifice of the sequencing valve during the second state of the valve and using a pressure drop across the orifice to bias the sequencing valve to remain in the second state.

Abstract: Methods of steam flooding for stimulating hydrocarbon production are provided. In general, the methods comprise the steps of: (A) injecting a mutual solvent preflush fluid capable of dissolving oil into the near-wellbore region of at least a portion of a wellbore; (B) injecting an aqueous preflush fluid further comprising a surfactant capable of oil-wetting silica; (C) injecting a treatment fluid into the near-wellbore region, wherein the treatment fluid comprises a curable resin, and wherein: (i) when injected, the curable resin is in an uncured state; and (ii) after being cured, the curable resin is stable up to at least 350° F. (177° C.); and (D) driving steam to break through the near-wellbore region.

Abstract: Apparatus and methods for measuring solids in wellbore that include a bottom hole assembly having a sensor to measuring a characteristic indicative of solids in the wellbore. The measurement may be used to measure solids or solids suspended in fluid flow. The invention is useful for use in wellbore cleanouts. A computer model may be used and updated based on the measured characteristic. The input of measured characteristic and the updating of the computer model may be performed in real time whilst the wellbore cleanout operation is ongoing.

Abstract: A method for cleaning oil wells to increase the flow of oil thereof by use of a unique aqueous cleaning emulsion comprising of water, hydrocarbon solvent, detergent and mineral acid. This one step method provides for the simultaneously cleaning/removal of asphaltine and/or paraffin and scale. This method can be used alone or with the assistance of a wash tool which is a combination pressure and surge wash tool having a nipple assembly. A by-pass port is coupled to the nipple assembly and a diverter cup is coupled to the by-pass port. A plurality of pressure wash cups are positioned on the tool. A pressure wash port is located between the plurality of pressure wash cups and a pump shoe assembly is coupled to a bottom pressure wash cup.

Abstract: Methods and compositions for the treatment of subterranean formations, and more specifically, treatment fluids containing vitrified shale and methods of using these treatment fluids in subterranean formations, are provided. An example of a method is a method of displacing a fluid in a well bore. Another example of a method is a method of separating fluids in a well bore in a subterranean formation. An example of a composition is a spacer fluid comprising vitrified shale and a base fluid.

Abstract: Compositions are given that have high viscosities at one pH range and low viscosities at another pH range. Methods are given for using such compositions in oilfield treatments. In particular CT wellbore cleanout compositions and methods are given in which a viscous fluid is injected into a wellbore; the fluid entrains particles and carries them to the surface; the viscosity of the fluid is reduced by reducing or increasing the pH; the particles settle from the fluid; the viscosity of the fluid is increased by increasing or reducing the pH; and the fluid is re-injected into the wellbore. Suitable surfactants are anionic surfactants, or mixtures of surfactants containing anionic surfactants, that aggregate into three-dimensional structures that substantially increase the viscosity at high pH but not at low pH. Other suitable surfactants are cationic surfactants with co-surfactants that aggregate below a certain pH but not above.

Abstract: A composition is provided for delivering an organic solvent to a downhole portion of a wellbore for the production of hydrocarbon or to a portion of a pipeline for the transmission of hydrocarbon. The composition comprises: (A) water; (B) a weighting agent; (C) an organic solvent that is immiscible with water; and (D) a surfactant adapted for forming an oil-external emulsion of the organic solvent and the water, wherein the surfactant is unstable to hydrolysis. The composition is formed to be an oil-external emulsion. The density of the composition is formulated to be greater than that of pure water at standard temperature and pressure. A method is provided for delivering an organic solvent to a downhole portion of a wellbore for the production of hydrocarbon or to a portion of a pipeline for the transmission of hydrocarbon. The method comprises the steps of: (A) forming a composition according to the invention; and (B) introducing the composition into the wellbore or into the pipeline.

Abstract: A method for removal of deposits such as hydrate plugs from a pipeline is provided including inserting a thruster pig connected to a return flow line into the pipeline The pig is then advanced forward into the pipeline by pumping a thrusting fluid into an annulus between the pipeline and the return flow line while removing deposits continuously or intermittently and returning flow as appropriate from ahead of the pig through the return flow line. The return flow line is then disconnected from the pig after sufficient deposit removal and retrieved from the return flow line. Next, the pig may then be transported through the pipeline by the pipeline fluid to a pig receiving location once the pipeline flow is resumed.

Abstract: Methods of removing a fluid from a well bore with a chemical wash composition, and more particularly, methods of using chemical wash compositions comprising water, a sulfonated lignin, and a taurate are provided. In one embodiment, a method of at least partially removing a fluid from a well bore surface is provided that comprises: providing a chemical wash composition comprising water, a sulfonated lignin, and a taurate; and contacting the well bore surface with the chemical wash composition to thereby at least partially remove the fluid from the well bore surface.

Abstract: A method of foam emulsion well cleanout for gas well. An emulsifier apparatus is provided having a compressed air inlet, a foaming solution inlet and a foam outlet. The compressed air inlet is connected to a source of compressed air capable of supplying compressed air to the emulsifier apparatus within a range of selected pressures. The foaming solution is connected to a source of foaming solution capable of supplying foaming solution to the emulsifier apparatus within a range of selected pressures. The foam outlet is connected to a discharge conduit supplying foam to a gas well. The production of foam is initiated out of the foam outlet of the emulsifier apparatus by supplying compressed air to the emulsifier apparatus through the compressed air inlet at a rate of approximately 300 to 400 c.f.m. and at pressures within a range of 175 p.s.i and 375 p.s.i.

Abstract: A bottom-up method of fracturing a multi-zone subterranean formation intersected by a wellbore that enables one zone to be fractured while at the same time flowing previously placed fracture fluid from one or more other zones back to the surface is provided. The method employs a bottom-hole assembly (“BHA”) that is attached to the bottom end of a tubing string. The BHA includes a hydra jetting sub, a centralizer, a packer and valve sub. The hydra jetting sub is used to perforate and initiate the fracture in the zones of interest. The zones are fractured by pumping fracturing fluid down the annulus formed between the tubing string and the wellbore. The previously placed fracture fluid flows back to the surface through the tubing string. It enters through the valve sub in the BHA.

Abstract: Fluids, such as completion fluids, containing at least one alkali metal tungstate and optionally at least one chelating agent are described. Methods of removing a filter cake from a well bore surface, which may include one or more alkaline earth metal sulfates, is also described, wherein the method includes contacting the filter cake with the completion fluid of the present invention. A drilling fluid or mud is also described wherein the drilling fluid contains at least one alkali metal tungstate. The drilling fluid preferably further contains at least one emulsifier or surfactant and at least one hydrocarbon-based fluid. The various fluids of the present invention can contain other conventional ingredients and optionally at least one alkali metal formate. The present invention permits the fluids to be essentially solids free due to the use of the alkali metal tungstate.

Abstract: Methods for treating wellbores using fluids containing a sphingan heteropolysaccharide which contributes viscosity stability and a decrease in friction pressure. Some methods are clean-out operations using recyclable-viscosity fluids containing at least a sphingan heteropolysaccharide and an optional salt. Others include methods of pumping fluids incorporating sphingan heteropolysaccharides to reduce pumping frictional pressure.

Abstract: An improved method of controlled energy delivery utilizing solid, liquid, and gaseous carbon dioxide (CO2) into a water well and the surrounding aquifer to remove deposited material which may cause loss of capacity in wells and a variety of water quality problems. After proper study and evaluation of problems associated with a well to be treated, adequate injection of the required amount of CO2 and energy is achieved by real-time monitoring during the injection and manipulating the phase changes in the CO2 that take place in the well and the aquifer.

Abstract: A formulation containing a copolymer derived from a cationic monomer effectively inhibits and controls the formation of inorganic scales. The formulation has particular application in the removal of zinc sulfide and iron sulfide scales formed when zinc bromide brines are used as completion fluids. The copolymer exhibit high solubility in high-density brines, such as zinc bromide brines. The polymers may be introduced into an oil or gas well as a portion of a carrier fluid or with brine. The preferred copolymer for use in the invention contains an acrylamide unit and a diallyldimethylammonium salt and, optionally, an acrylic acid or a salt thereof. The weight average molecular weight of such inhibitor copolymers is generally between from about 500,000 to about 5,000,000.

Abstract: Methods of increasing the permeability of a portion of a subterranean formation may comprise providing a remediation fluid capable of decreasing the tackiness of a tackifying agent, the remediation fluid comprising a surfactant; introducing the remediation fluid into the portion of the subterranean formation, wherein a plurality of tackified particulates at least partially coated with formation fines are located within the portion; and allowing at least a substantial portion of the formation fines to detach from the plurality of tackified particulates.

Abstract: A method that is usable with a well includes injecting a chemical through a chemical injection line into a flow that passes through a well pump. The method includes controlling the injection of the chemical to enhance the flow through the pump.

Abstract: Openings are created between a wellbore and a formation by firing a perforating gun adjacent to a zone in the formation and the production fluids are produced along with any formation debris. A tubing string extending to the formation is pressurized to actuate the perforating gun and simultaneously to actuate a downhole injection port. Substantially immediately thereafter fluids are injected into the wellbore near the openings and circulated to the surface for the removal of debris and the production of the formation fluids. An optional and uphole injection port can be used to adjust the hydrostatic head above the perforating gun with the removal or addition of fluid prior to actuation. The tubing string extends sufficiently above the wellbore at surface to enable lowering of the downhole injection port below the openings during fluid circulation for enhanced removal of debris.

Abstract: Methods of initiating a fracture tip screenout, that comprise pumping an annulus fluid into an annulus, between the subterranean formation and a work string disposed within a wellbore penetrating the subterranean formation, at an annulus flow rate; and reducing the annulus flow rate below a fracture initiation flow point so that the fracture tip screenout is initiated in the one or more fractures in the subterranean formation, are provided. Also provided are methods of fracturing a portion of a subterranean formation and methods of estimating a fracture initiation flow point.

Abstract: A method of treating a well consists of introducing into the wellbore a biodegradable fluid system containing a blend of lactic acid ester, such as ethyl lactate, and a fatty acid ester, such as methyl soyate. The fluid system may be further in the form of a microemulsion that is formed by combining a blend with one or more emulsifiers, an alcohol, and water. The fluid system may be used in displacement, well remediation and stimulation as well as additional, alternative applications such as the cleaning of surface and/or downhole equipment.

Abstract: Wellbore servicing fluids and methods of using the same to service a wellbore in a subterranean formation are provided. A filter cake in the wellbore is contacted with the gravel packing fluid, which comprises an oil-soluble additive capable of removing the filter cake. The additive undergoes hydrolysis to produce an acid upon contacting water provided from, for example, water in the wellbore servicing fluid, connate water in the subterranean formation, water in the filter cake, water produced by the subterranean formation, water pumped into the wellbore, or combinations thereof. The acid dissolves particulates in the filter cake in situ. In an embodiment in which the wellbore servicing fluid serves as a gravel packing fluid, the fluid also deposits gravel along the face of the subterranean formation, forming a barrier against the migration of sand from the formation and into the wellbore.

Abstract: Hydrocarbon solids are removed from an oil well by feeding into the oil well a composition comprising at least 40 vol. % dense phase carbon dioxide and at least 30 vol. % of a C1–C3 alkanol component and optionally one or more surfactants, under a pressure of 300 to 10,000 psia and a temperature of 90° F. to 120° F., holding the composition in the well to solubilize hydrocarbon solids, and then removing from the well a liquid composition comprising solubilized hydrocarbon solids and alkanol.

Abstract: An aqueous-based composition containing cesium formate and at least one chelating agent is described. Methods of removing scaling deposits, which may include alkaline earth metal sulfates, present on surfaces, including porous media, such as alkaline earth metal sulfate buildup in a well bore, is also described, wherein the method includes contacting the alkaline earth metal sulfate with the compositions of the present invention to remove the scaling deposits. A completion fluid containing at least one alkali metal formate, at least one acid and/or at least one chelating agent, and optionally at least one surfactant or mutual solvent is also described. Methods of removing a filter cake from a well bore surface, which may include weighting agents such as calcium carbonate, is also described, wherein the method includes contacting the filter cake with the completion fluid of the present invention.

Abstract: Method and apparatus for servicing of a bore hole in the earth, comprising a first sub-assembly adapted for the insertion and removal of a continuous length of coiled tubing into and from the bore hole, a second sub-assembly adapted for the vaporization of liquified gas and the pumping of the resulting gas through the coiled tubing into the bore hole and a platform to support both the first and second sub-assemblies thereon.

Abstract: Systems for implementing methods for generating platform location sets comprising selecting a set of platform locations; determining additional platform locations to add to the set of platform locations; validating the additional platform locations, and determining an optimum location for each platform location in the set of platform locations.

Abstract: The present invention relates to methods and compositions for degrading filter cakes in subterranean formations, and more specifically, to improved methods and compositions for degrading filter cakes that comprise acid-soluble portions and polymeric portions.

Abstract: Fluid producing wells may be treated with a water-in-oil emulsion for the removal or inhibition of unwanted solid particulates, including pipe dope, asphaltenes and paraffins. Such emulsions are of particular applicability in the displacement of oil base drilling muds and/or residues from such muds from producing wells. The water-in-oil emulsions may optionally contain a dispersing agent as well as a surfactant.

Abstract: Invert emulsion compositions including an oleaginous, a non-oleaginous and an amine surfactant that are useful in the oil and gas well drilling art are disclosed. The amine surfactant is selected so that the invert emulsion can be converted form a water-in-oil type emulsion to a oil-in-water type emulsion upon the protonation of the amine surfactant. Deprotonation of the amine surfactant reverses the conversion. This solution also permits the conversion of oil-wet solids in the fluid into water-wet solids.

Abstract: An oil-based demulsifying formulation which can be used in the treatment of drains bored in oil-based mud, non ecotoxic and optimally compatible with formation fluids, comprises at least one wetting agent chosen from anionic surfacetants and at least one demulsifier (or “emulsion breaker”) chosen from copolymers of ethylene oxide and propylene oxide, alcohol or phenol derivatives with alkoxylated or polyalkoxylated chain formations, polyalkyleneglycols, polyamines, alkoxylated or polyalkoxylated derivatives of amines, quaternary ammonium salts, quaternized alkanolamine esters, alkyl esters of fatty acids or natural oils, possible alkoxylated or polyalkoxylated, and silicated derivatives such as polysiloxanes.

Abstract: Methods and compositions for breaking treatment fluids utilized in the stimulation of a subterranean formation.

Abstract: A formulation containing a copolymer derived from a cationic monomer effectively inhibits and controls the formation of inorganic scales. The formulation has particular application in the removal of zinc sulfide and iron sulfide scales formed when zinc bromide brines are used as completion fluids. The copolymer exhibit high solubility in high-density brines, such as zinc bromide brines. The polymers may be introduced into an oil or gas well as a portion of a carrier fluid or with brine. The preferred copolymer for use in the invention contains an acrylamide unit and a diallyldimethylammonium salt and, optionally, an acrylic acid or a salt thereof. The weight average molecular weight of such inhibitor copolymers is generally between from about 500,000 to about 5,000,000.