Abstract: A fracturing tool features spaced releasable packers with an outlet in between. The housing has relatively moving components for opening the frac port between the packers with weight set on the lower packer. Once the frac port is opened the upper packer is set and the pumping begins. The upper packer can be released so that tension can be pulled on the lower packer to close the frac port and open a through passage in the housing. In one embodiment the through passage can be located above the lower packer to a sand jet perforator to clean debris away from the lower packer if it is difficult to release the lower packer or to abrasively perforate through a tubular. The housing outlet can be below bottom packer to perform a treatment further downhole or to operate another tool. The straddle tool can be run in on coiled tubing.

Abstract: Methods for treating an oil well having a wellbore. The methods involve injecting a microemulsion into the wellbore to increase formation crude oil production by the well. The microemulsion comprises water, a first type of solvent and a first type of surfactant. The microemulsion includes a continuous water phase.

Abstract: A portion of a drilling fluid waste is injected into a well. A cross-sectional dimension of solids in a slurry is reduced. The slurry includes the drilling fluid waste. A property of the slurry, of the well, or both is measured. A model is obtained based at least partially upon the property. The model represents an interaction of the slurry with the well. An additive is introduced into the slurry in response to measuring the property, generating the model, or both. The slurry is injected into the well after the additive is introduced.

Abstract: A method of treating particles of a particle pack located in a subterranean formation comprising: introducing an additive into the subterranean formation, wherein the additive: (i) comes in contact with the particles of the particle pack; (ii) has a chemical attraction to the particles of the particle pack; and (iii) comprises a first functional group, wherein the first functional group is a water-control agent.

Abstract: A downhole tool deployable within a wellbore for controlling the supply of treatment to fluid to a reservoir is disclosed. The downhole tool includes a housing defining a passage and a port extending through the housing. The housing includes a seat that is configured for deployment to a plug-receiving position for receiving a plug that is deployed through the passage. A key profile for effecting actuation of the seat to the plug-receiving position in response to registration of the key profile with a matching key on the plug being deployed through the passage is provided. The downhole tool further includes a flow control member configured for displacement relative to the port in response to application of a sufficient net force effected by a fluid pressure differential that is created by supplying pressurized fluid to the passage while the plug is deployed on the seat.

Abstract: Novel fracturing fluid compositions including a polymers system including a major portion of one synthetic hydratable polymer or a plurality of synthetic hydratable polymers, and a minor portion of one natural hydratable polymer or a plurality natural hydratable polymers, and an effective amount of a viscosifying system including one guanidine salt or a plurality of guanidine salts, where the effective amount is sufficient to increase the viscosity of the synthetic polymer system by 20% or more compared to fracturing fluids including only the synthetic polymer system and methods for making and using the compositions.

Abstract: A method for injecting a portion of a drilling fluid waste into a well includes separating solids from the drilling fluid waste to produce a filtered drilling fluid waste. A cross-sectional dimension of at least a portion of the solids is reduced. The filtered drilling fluid waste is combined with the at least a portion of the solids that were reduced in dimension to produce a slurry. A property of the slurry is measured. The property is adjusted in response to measuring the property. The slurry is injected into the well.

Abstract: An apparatus for selectably isolating a subterranean formation from a production string comprises a radially expandable ring located between upper and lower sleeves and retained at a position to intrude into a central passage extending therethrough. The expandable ring is permitted to radially expand into a recess upon displacement of the lower sleeve to permit a body retained thereon to move therepast. The apparatus includes a pair of inner and outer indexing rings which cooperate to permit the inner and outer indexing rings to move towards a bottom end thereof only to a fixed endwall whereafter further movement of the inner and outer indexing rings and lower sleeve is prevented.

Abstract: Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations, and methods of selecting a composition for treating an oil or gas well. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant.

Abstract: Methods for reducing loss of wellbore fluid to formation may include pumping an oil-based wellbore fluid into the wellbore, where the wellbore includes an oleaginous continuous phase and a plurality of modified brine phases dispersed in the oleaginous continuous phase.

Abstract: Methods for acidizing subterranean formations may include introducing into a wellbore penetrating the subterranean formation having a temperature of about 275° F. or greater a treatment fluid comprising an aqueous fluid, a Lewis acid catalyst and a precursor; wherein the precursor is selected from the group consisting of a saccharide, a saccharide derivative, and a combination thereof; and reacting the precursor and the Lewis acid catalyst to yield an organic acid in a portion of the subterranean formation, a portion of the wellbore, or both.

Abstract: A method of servicing a wellbore comprising providing a degradable polymer and a delayed action construct within a portion of a wellbore, a subterranean formation or both; wherein the delayed action construct comprises (i) a degradation accelerator comprising an alkanolamine, an oligomer of aziridine, a polymer of azridine, a diamine, or combinations thereof, (ii) a solid support, and (iii) an encapsulating material; and placing the wellbore servicing fluid comprising the degradable polymer and delayed action construct into the wellbore, the subterranean formation or both.

Abstract: A method of treating a treatment zone of a subterranean formation penetrated by a wellbore of a well, the method including the steps of: (A) forming a treatment fluid comprising: (i) an aqueous phase comprising water having at least 1,000 ppm total dissolved inorganic salts; (ii) a carboxymethyl hydroxyethyl cellulose, wherein: (a) the carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution is in the range of about 0.3 to about 0.45 per glucopyranose unit in the polymer; and (b) the carboxymethyl hydroxyethyl cellulose has a hydroxyethyl molecular substitution is in the range of about 2.1 to about 2.8 per glucopyranose unit in the polymer; and (iii) a breaker for the carboxymethyl hydroxyethyl cellulose; and (B) introducing the treatment fluid into the treatment zone. In embodiments, the carboxymethyl hydroxyethyl cellulose may or may not be crosslinked.

Abstract: Methods and compositions for stimulating of the production of hydrocarbons (e.g., formation crude oil and/or formation gas) from subterranean formations are provided. In some embodiments, the compositions are emulsions or microemulsions, which may include water, a terpene, and a surfactant. In some embodiments, methods of selecting a composition for treating an oil or gas well are provided.

Abstract: Provided herein are cementitious compositions comprising a non-aqueous fluid and an alkali-activated material. The non-aqueous fluid can include a natural oil, a synthetically derived oil, one or more surfactants, or a combination thereof. In some embodiments, the non-aqueous fluid can include an oil based mud, a synthetic based mud, or a mixture thereof. The alkali-activated material in the cementitious composition can be derived from an aluminosilicate material and an alkaline activator. In some embodiments, the aluminosilicate material includes fly ash. The alkaline activator can be selected from an alkali-hydroxide, an alkali-silicate, an alkali carbonate, an alkali bicarbonate, an alkali sulfate, and a mixture thereof. Provided herein are also wellbore servicing composition, such as compositions to reduce lost circulation of drilling fluids or cement a casing into the borehole, comprising the cementitious compositions and methods for preparing and using the cementitious compositions.

Abstract: A method of conducting multiple stage treatments. The method includes running a string into a borehole. The string having at least a first sleeve assembly and a second sleeve assembly. The first sleeve assembly in a position closing a port in the string; communicating from a radial exterior of the string or from a location downhole of the first and second sleeve assemblies to a first electronic trigger of the first sleeve assembly to trigger the first sleeve assembly into moving longitudinally relative to the string to open the port. Performing a treatment operation through the port; communicating from the radial exterior of the string or from a location downhole of the first and second sleeve assemblies to a second electronic trigger of the second sleeve assembly to trigger the second sleeve assembly into moving longitudinally relative to the string to close the port.

Abstract: A water injection system that includes a primary water injection line; an injection fluid supply tank; a high pressure injection pump in fluid communication with the injection fluid supply and primary water injection line for pumping injection fluid in injection fluid supply tank through the primary water injection line; a polymer gel supply tank; and a high pressure chemical injection pump in fluid communication with the polymer gel supply tank and the water injection line configured to pump polymer gel having a viscosity of at least about 50,000 cP (at 20° C. measured using a Bohlin Rheometer CSR 50, cone and plate measuring system CP 4°/40 mm, single shear rate 1/s) in the polymer gel supply tank into the water injection line for mixture with injection fluid is disclosed.

Abstract: A method of inhibiting scale in a geological formation comprising depositing a binder on the formation surface, delivering a nano-material to the surface where it chemically interacts with the binder, emplacing a scale inhibitor on the formation that is absorbed by the nano-material, where a sustained release of the scale inhibitor into the geological formation results.

Abstract: Embodiments including methods comprising providing a treatment fluid comprising a first aqueous base fluid and a polymeric gelling agent, wherein the treatment fluid comprises a first surface tension; introducing a fluid mobility modifier into the treatment fluid, wherein the fluid mobility modifier comprises: a first surfactant selected from the group consisting of a non-ionic surfactant; a cationic surfactant; and any combination thereof, and a solvent-surfactant blend comprising a second aqueous base fluid, a second surfactant, a solvent, and a co-solvent, wherein the ratio of the first surfactant to the solvent-surfactant blend is in the range of between about 1:5 to about 5:1, wherein the fluid mobility modifier causes the treatment fluid to adopt a second surface tension that is less than the first surface tension; and introducing the treatment fluid into a subterranean formation.

Abstract: An electrophilic acid gas-reactive fracturing fluid, proppant, and process are detailed. The fluid expands in volume to provide rapid and controlled increases in pressure that enhances fracturing in subterranean bedrock for recovery of energy-producing materials. The proppant stabilizes fracture openings in the bedrock to enhance recovery of energy-producing materials.

Abstract: A method for controlling water passage from an interval undergoing hydraulic fracturing to another interval in the same or a different well bore. The method introduces a relative permeability modifier at a pressure sufficient to create or enhance at least one fracture and fracture face in the subterranean formation surrounding the interval during fracturing. The method can reduce the water passage between two or more intervals of a well bore and between two or more well bores. The method can reduce the amount of water produced from a well, which reduces the processing necessary to remove water from the hydrocarbons produced from the well.

Abstract: A mineral-compatible cationic emulsion composition with polymer stabilizers, and methods for utilizing same in paving and other applications is disclosed. In one aspect, a bitumen-in-water emulsion composition includes at least one bitumen material, at least one polymer stabilizer, at least one emulsifier, and water, where the emulsifier is a cationic surfactant, an amphoteric surfactant, or a mixture of both, and the polymer stabilizer is a natural or synthetic cationic polymer consisting of alkylene polyamines, alkyl polyamines, polyquaternary polymers, polyvinylamine, polyvinylimidazoline, polyester polyquaternary polymers, polyether polyquaternary polymers, or mixtures thereof. The inclusion of polymer stabilizer in the cationic emulsion increases the stability of the emulsion and increases the compatibility of the cationic emulsion with negatively charged minerals.

Abstract: A method relating to perforation operations, which comprises introducing a wettability altering fluid into a wellbore extending into a subterranean formation such that the wettability altering fluid seeps into the subterranean formation. Subsequent to introducing the wettability altering fluid, a fluid loss pill is introduced into the wellbore such that seepage of fluid between the wellbore and the subterranean formation is inhibited.

Abstract: Methods and compositions comprising an emulsion or a microemulsion for use in various aspects of the life cycle of an oil and/or gas well are provided. In some embodiments, the emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives.

Abstract: This is a system that stores energy by compressing atmospheric air and confining it in tanks or caverns, combining the thermodynamic cycle followed by the atmospheric air (Brayton cycle) with another thermodynamic cycle followed by an auxiliary fluid, that is confined in the same cavern within a membrane, following two sections of a Rankine cycle, one during the air compression and entry into the cavern process and the other during the air outlet and turbining process, using heat from the exhaust gases from the turbine as a heat source for an additional Rankine cycle, and being able to use the tanks or caverns for making an extra constant volume heating of compressed air and/or of the auxiliary fluid.

Abstract: The current application aims at methods and systems for preparing a pump-ready treatment fluid, delivering the pump-ready treatment fluid to a location operationally coupled to a wellsite, providing the pump-ready treatment fluid to a pump; and pumping the pump-ready treatment fluid into a wellbore. In some embodiments, the treatment fluid is a fracturing fluid for conducting a hydraulic fracturing operation on a subterranean formation penetrated by a wellbore.

Abstract: A treatment fluid comprises: a liquid fluorinated compound; and at least one additive, wherein the additive: (A) comprises carbon and at least one fluorine functional group; and (B) is soluble or dispersible in the liquid fluorinated compound. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well.

Abstract: A heating system for heating a natural gas hydrate reservoir. The heating system includes a fully enclosed wellbore extending through a portion of the natural gas hydrate reservoir. A heating fluid is passed through the wellbore to heat the portion of the natural gas hydrate reservoir. Additionally, a production system includes a perforated wellbore that is used to extract the natural gas hydrate water after heating.

Abstract: A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports.

Abstract: Described herein are compositions for use in treating subterranean formations where the compositions include a water soluble polymer and an ionic surfactant. In preferred compositions, the polymer and surfactant are oppositely charged. Methods of using the compositions also are disclosed.

Abstract: Systems and methods for creating and/or using multi-functional surfactant complexes that may enhance surfactant treatments in subterranean formations are provided. In some embodiments, the methods comprise: providing a treatment fluid comprising an aqueous base fluid and one or more multi-functional surfactant complexes that comprise at least one surfactant and at least one polymeric additive, wherein the surfactant and the polymeric additive carry opposite charges; and introducing the treatment fluid into a well bore at a well site penetrating at least a portion of a subterranean formation.

Abstract: An aqueous slurry composition for use in industries such as the petroleum and pipeline industries includes a particulate, an aqueous liquid and a chemical compound that renders the particulate surface extremely hydrophobic. The slurry is produced by rendering the surface of the particulate extremely hydrophobic during or before making the slurry.

Abstract: The present invention relates to the petroleum drilling field and discloses a reservoir protecting agent composition comprising a structured nanometer film reservoir protecting agent and a water block preventing agent, a drilling fluid containing the same and use thereof for drilling in low-permeability reservoirs. The reservoir protecting agent composition comprises a structured nanometer film reservoir protecting agent and a water block preventing agent, wherein the structured nanometer film reservoir protecting agent comprises montmorillonite laminas, structural units represented by formula (1) and structural units represented by formula (2), wherein each of R1, R2, R3, R4 and R5 is independently selected from H, C1-C4 alkyl and C1-C4 alkoxy, R6 is C1-C6 alkylene. The present invention further provides a drilling fluid that contains the reservoir protecting agent composition according to the present invention.

Abstract: Systems and methods of treating a zone of a subterranean formation penetrated by a wellbore are described. A composition may include a first solution including at least one amine containing resin; and citraconic anhydride. The composition may also include a second solution mixed with the first solution, where the second solution includes at least one epoxide containing resin. Methods may include providing the treatment fluid to a subterranean formation.

Abstract: A liquid treatment method includes mixing a liquid with an agent to form a mixture, aging the mixture to obtain to a predetermined condition in at least one of the liquid and the agent, and dispensing the aged mixture. An interaction between the liquid and the agent causes the predetermined condition to occur. Also, a majority of the aging occurs while the mixture is in a dynamic state. A related system includes a mixer receiving a liquid and a drag reducing agent and an aging module connected to the mixer. The mixer disperses the drag reducing agent in the liquid to form a mixture and the aging module has a flow path along which the mixture flows. The flow path has a distance sufficient for a majority of the aging to occur while the mixture is in a dynamic state, wherein the aging changes the drag reducing agent to a predetermined condition.

Abstract: A method of completing a well includes, pumping treating fluid into a tool string in the well, displacing drilling mud within the tool string with the treating fluid, and treating an earth formation with the treating fluid.

Abstract: The present invention relates to a polymer including at least one monomer comprising a switchable-amphiphilic functional group. Various embodiments provide a methods of treating a subterranean formation with the polymer, compositions including the polymer, and methods of making compositions including the polymer.

Abstract: Air and ammonia gas are introduced into a subterranean formation during the in-situ combustion to increase the mobility of hydrocarbons in a subterranean formation and facilitate recovery of the hydrocarbons from the subterranean formation. The air supports in-situ combustion of a portion of the hydrocarbon within the subterranean formation to form water and establish a combustion front. The ammonia gas contacts the hydrocarbons ahead of the combustion front and reacts in-situ with naphthenic acid in the hydrocarbon to form a surfactant. The hydrocarbons, water and surfactant then form an oil-in-water emulsion that drains more freely through the formation. A production well, in fluid communication with the hydrocarbons ahead of the combustion front, may be used to remove the oil-in-water emulsion from the subterranean formation.

Abstract: The present disclosure relates generally to devices and methods useable during well drilling operation. More particularly, the present disclosure pertains to a drilling rig incorporating a dual top drive apparatus useable for decreasing connection time of pipe segments useable during well drilling or other well operations, and methods of connecting pipe segments useable during well drilling or other operations.

Abstract: The invention relates to the storage of contaminated material under a water layer, in particular the storage of bottom ash. The invention provides for this purpose a method for storing a contaminated material under a water layer, comprising the processing steps of supplying the contaminated material, supplying ground material, mixing the contaminated material with the ground material and arranging the mixture of contaminated material and ground material in or under a retention layer situated under a water layer, and wherein the mixture is not in contact with the water layer, and the retention layer comprises ground material. The invention also provides an installation for storing contaminated material and a composition comprising the contaminated material.

Abstract: A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an amino multicarboxylic acid chelating agent, a pH adjusting compound, and an aqueous base fluid, and contacting the wellbore servicing fluid with scale deposits on a surface in fluid communication with the wellbore and/or subterranean formation.

Abstract: Enhanced oil recovery becomes increasingly important in satisfying the growing demand for fossil fuel. The efficiency of secondary recovery processes like water flooding is however largely influenced by the rock characteristics, fluid characteristics, chemistry and physics. For development of the full potential of secondary oil recovery, it remains a challenge to obtain sufficient knowledge about the reservoir conditions. The present invention provides a novel water-dispersed, nano-sensor composition based on. InP/ZnS quantum dots (“QDs”) and atomic silver clusters, which exhibit a bright visible fluorescence combined with dedicated sensor functionalities. The QD and silver nano-sensors were tested in simulated reservoir conditions to determine their selected functionality to these reservoir conditions. The developed nano-sensors showed improved sensor functionalities towards pH, temperature, and subterranean reservoir rock, such, as clay or limestone.

Abstract: Downhole nuclear magnetic resonance (NMR) methods that utilize oleophilic nanoparticle may allow for differentiation of light oil and oil-based filtrates. For example, a method may involve drilling a wellbore penetrating a subterranean formation using an oil-based drilling fluid that comprises an oil base fluid and a plurality of oleophilic nanoparticles; performing a plurality of NMR measurements at a plurality of depths of investigation (DOI) of a near-wellbore portion of the subterranean formation; and producing an invasion profile of an oil-based drilling fluid filtrate into the near-wellbore portion of the subterranean formation based on the plurality of NMR measurements.

Abstract: Gelled barrier fluids preventing the ingress of undesired fluids from subsurface environments into subsurface apparatus have a specific gravity which is within ±0.05 of the specific gravity of the undesired fluid.

Abstract: Compaction aid compositions and methods for compacting soils, sands, and other aggregates are described herein. In particular, the compaction aid compositions can comprise at least one synthetic fluid that was previously derived from a Gas-to-Liquids process. The compactions aids can be used to efficiently and effectively compact various soils, sands, and other aggregates at temperatures below the freezing point of water, thereby making such compaction aids highly useful in arctic and subarctic environments.

Abstract: A method and system for removing solids or displacing a fluid from a wellbore wherein a plurality of resilient rubber-like flexible reticulated open cell foam elements are dispersed in a fluid and pumped through drill pipe and into the annulus between the wellbore and the drill pipe. In the annulus, the foam elements impact and dislodge solids such as proppants, gravels, drilled cuttings and other solids or a fluid to be displaced and the proppants, etc. or the fluid are carried by the fluid containing the foam elements back to the surface or a different location in the wellbore. At the surface, the fluid containing the foam elements and the proppants, etc., is carried to a shale shaker where the solids and the foam elements are separated from the fluid. The separated solids and foam are collected for disposal and, after adding new foam elements, the fluid can be recirculated down hole.

Abstract: A wellbore treatment apparatus includes: a tubing string including a wall defining an inner diameter and a port extending through the wall, the port closed by a closure including a plug-actuated sliding sleeve; and a port opening apparatus including a wireline deployable through the inner diameter of the tubing string to extend to a position adjacent the plug-actuated sliding sleeve and an actuator plug carried on and axially slideable along the wireline, the actuator plug sized to land in the plug-actuated sliding sleeve to actuate the plug-actuated sliding sleeve, while remaining on the wireline. The apparatus can be employed in a method by running the tubing string into a well, placing the slickline in the string and running the actuator plug along the wireline to land on and actuate a sleeve in the string.

Abstract: A frac sleeve system includes an outer sleeve with openings, an inner sleeve with ports, a pressure seat, a bottom locking device and a spring device. In a closed configuration of the inner sleeve, the openings and ports are not aligned for any fluid connection. In an opened configuration, at least one opening is aligned with at least one port for a fluid connection through the system. The inner sleeve shifts back and forth between configurations according to the pressure seat and the spring. The interaction of a guide pin on the outer sleeve and the guide slot on the inner sleeve controls the rotational and longitudinal movement of the inner sleeve along the common axis of the inner sleeve and outer sleeve so that there is unlimited shifting between configurations. The locking devices and spring device are also reuseable for the multiple shifting.

Abstract: A fracture plug seat assembly used in well stimulation for engaging and creating a seal when a plug, such as a ball, is dropped into a wellbore and landed on the fracture plug seat assembly for isolating fracture zones in a well. The fracture plug seat assembly has a fracture plug seat that includes elastomeric material and reinforcing material.

Abstract: A composition and method for performing a treatment of a subterranean formation. The composition includes an emulsified acid and a sulfobetaine surfactant. The emulsified acid and the sulfobetaine surfactant may be mixed to form a treatment composition, which may be injected into a subterranean formation as part of an acid fracturing or hydraulic fracturing treatment.