| Entries |
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| 20080251255 | STEAM INJECTION APPARATUS FOR STEAM ASSISTED GRAVITY DRAINAGE TECHNIQUES - Steam injection pipe string apparatus is disclosed comprising an elongated tubular structure with first and second ends, and a plurality of orifices formed in the elongated tubular structure. The sizes of the orifices vary from one end of the elongated tubular structure to the other, and, in one embodiment, the sizes of the orifices increase from one end of the elongated tubular structure to the other. The elongated tubular structure may comprise a plurality of blank pipes in threaded engagement with one another or a plurality of subs with different sized orifices in the subs. The orifices may be formed in the elongated tubular structure using milling techniques or by inserting a nozzle in a threaded aperture formed in the structure. A system utilizing the steam injection pipe string apparatus is especially suitable for use in a steam assisted gravity drainage system. | 10-16-2008 |
| 20080271893 | Method and Apparatus for Continuously Injecting Fluid in a Wellbore While Maintaining Safety Valve Operation - A kit for converting an existing wireline retrievable surface controlled subsurface safety valve ( | 11-06-2008 |
| 20080277119 | Method and Apparatus to Hydraulically Bypass a Well Tool - Apparatuses and methods to communicate with a zone below a subsurface safety valve ( | 11-13-2008 |
| 20080283247 | PORTABLE AND MODULAR SYSTEM FOR EXTRACTING PETROLEUM AND GENERATING POWER - An embodiment is a portable, modular apparatus, having one or more modules, for recovering oil from an oil well and generating electric power, and including a chassis to support a fuel reformer, a gas separator, a power generator, and/or a compressor. The fuel reformer module is adapted to react a fuel source with water to generate driver gas including a mixture of carbon dioxide gas and hydrogen gas. The gas separator module is operatively coupled to the reformer module and is adapted to separate at least a portion of the hydrogen gas from the rest of the driver gas. The power generator module is operatively coupled to the gas separator module and is adapted to generate electric power using a portion of the separated hydrogen gas. The compressor module is operatively coupled to the reformer module and is adapted to compress a portion of the driver gas, and to eject the driver gas at high pressure into the oil well for enhanced oil recovery. The chassis may be mounted and carried by a truck, boat, airplane, or other vehicle to the location of the oil well. | 11-20-2008 |
| 20090020289 | Secondary oil recovery - A process for injecting water into a subterranean petroleum-bearing formation for petroleum recovery, said method comprising: a) positioning a selective membrane between an aqueous solution and formation water having a higher solute concentration than the aqueous solution, such that water passes across the membrane by osmosis to dilute the formation water, b) injecting the diluted formation water into the petroleum-bearing formation, c) recovering formation water from the petroleum-bearing formation, and d) using at least a portion of the recovered formation water in step a). | 01-22-2009 |
| 20090084553 | SLIDING SLEEVE VALVE ASSEMBLY WITH SAND SCREEN - A system and method for completing a well with multiple zones of production is provided, including a casing having a plurality of valves integrated therein for isolating each well zone, establishing communication between each underlying formation and the interior of the casing, delivering a treatment fluid to each of the multiple well zones, and filtering produced fluids from each underlying formation. | 04-02-2009 |
| 20090095482 | Method and System for Centralized Well Treatment - A method of servicing multiple well locations from a central location is disclosed that includes the steps of configuring a central location for distribution of well development task fluids to centralized service factories through fluid lines; preparing the treatment fluids at the centralized service factories; and treating wells with the treatment fluids according to well development tasks associated with each well. A system for centralized well treatment operations is disclosed that includes a centralized well treatment center which pumps well development task fluids to centralized service factories; a plurality of systems with well development mechanisms; a first connection and second connection between a well and the centralized service factories, wherein the connections are directed to flowing and recovering treatment fluids respectively; a third and fourth connection between another well and the well treatment factory, wherein the connections are directed to flowing and recovering treatment fluids respectively. | 04-16-2009 |
| 20090095483 | INSTALLATION FOR ENHANCED OIL RECOVERY USING WATER-SOLUBLE POLYMERS, METHOD IMPLEMENTING SAME - Installation for enhanced oil recovery comprising in succession: a polymer storage hopper, a grinding device and a pressurized injection pump. The grinding device has a chamber for grinding and draining the dispersed polymer comprising a rotor and a stator, and on all or part of the periphery of the chamber, a ring fed by a secondary water circuit. The ring communicates with the chamber for spraying of pressurised water on the blades of the stator. A method implementing the installation is also provided. | 04-16-2009 |
| 20090114391 | METHOD FOR AUTONOMOUS CONTROL OF A CHEMICAL INJECTION SYSTEM FOR OIL AND GAS WELLS - A control program for a positive displacement metering system measures the time required for the travel of a free piston in a cylinder of known volume to determine an average flow rate during a full stroke of the piston. The system may also measure and record the inlet and outlet pressures or the differential pressure between the fluid inlet and outlet. The control program positions a four-way valve which may function as an adjustable metering orifice in response to the measured average flow rate and/or changes in the inlet and outlet pressures to achieve the desired flow rate. At the end of each stroke, the four-way valve is repositioned to reverse fluid flow through the metering cylinder. The system may revise the valve position settings for both forward and reverse strokes based on the measured time required for a full stroke at a certain valve position. In this way, the system automatically and iteratively compensates for changes in fluid properties and fluid pressure. A cleaning cycle which progressively opens the valve stepwise and may culminate in full open valve travel in both fluid flow directions is provided in the event of an obstruction of the valve orifice. | 05-07-2009 |
| 20090114392 | Method and Apparatus Associated With Stimulation Treatments for Wells - A method and apparatus associated with the production of hydrocarbons. In one embodiment, the method describes connecting multiple wells to a stimulation fluid pumping system via a pumping system manifold. The pumping system manifold is adjusted to provide a first well flow path from the stimulation fluid pumping system to a first well. Then, a first stimulation treatment is pumped into the first well. Concurrently with the pumping of the first stimulation treatment, a second well is prepared for a second stimulation treatment. | 05-07-2009 |
| 20090114393 | DIVERTER VALVE - Apparatus for multi-zone wellbores that can by-pass upper hydrocarbon bearing zones and deliver fluid to lower hydrocarbon bearing zones. The apparatus can include at least one housing, and at least one port can be formed through the housing. An inner sleeve can be positioned within the housing. At least one cavity can be radially disposed on an outer diameter of the inner sleeve, and each cavity can be located within an annulus formed between the inner sleeve and the housing. A ball can be disposed within each cavity, and the ball can be adapted to selectively engage the port. | 05-07-2009 |
| 20090151952 | ENERGIZED FLUIDS AND PRESSURE MANIPULATION FOR SUBSURFACE APPLICATIONS - Method and system for use in a subsurface formation traversed by a wellbore. An energized fluid, which when subjected to a low pressure environment liberates or releases gas from solution, is disposed in the formation. Reduced pressure in a region of the wellbore below pressure in the surrounding formation liberates a gas in the energized fluid near a tunnel created in the formation. | 06-18-2009 |
| 20090166042 | PURGING OF FIBER OPTIC CONDUITS IN SUBTERRANEAN WELLS - Purging of fiber optic conduits in subterranean wells. A downhole optical sensing system includes an optical line, at least two tubular conduits, one conduit being positioned within the other conduit, and the optical line being positioned within at least one of the conduits, and a purging medium flowed in one direction through one conduit, and flowed in an opposite direction between the conduits. A method of purging a downhole optical sensing system includes the steps of: installing at least two conduits and an optical line in a well as part of the sensing system, one conduit being positioned within the other conduit, and the optical line being positioned within at least one of the conduits; and flowing a purging medium through the conduits in the well, so that the purging medium flows in one direction through one conduit and in an opposite direction between the conduits. | 07-02-2009 |
| 20090200033 | COMPOSITIONS AND METHODS FOR GAS WELL TREATMENT - A microemulsion system is disclosed which comprises a solvent subsystem, a co-solvent subsystem and a surfactant subsystem comprises at least one monoalkyl branched propoxy sulfate anionic surfactant, where the microemulsion system are useful in drilling, producing, remediation, and fracturing application to reduce water blocks and water blocking in formation of a producing formation. | 08-13-2009 |
| 20090250221 | Method of supplying a powdered chemical composition to a wellsite - A method of conditioning a compacted polymeric powder to a flowable and meterable state. The polymeric powder is compacted during transport such that the flowability is hindered. To increase flowability, gas is introduced into the polymeric powder to condition the same to an improved flowable and meterable state. | 10-08-2009 |
| 20090255678 | Water Treatment by Chemical-Mechanical Process - Systems and methods for treating aqueous fluids and their associated methods of use are disclosed. In one embodiment, a method comprises providing an untreated aqueous fluid with a first concentration of a contaminant. The method further comprises chemically treating the aqueous fluid to precipitate at least a portion of the contaminant. The method further comprises mechanically treating the aqueous fluid to remove at least some of the precipitated contaminant from the aqueous fluid, and to produce a treated water with a second concentration of the contaminant, wherein mechanically treating the aqueous fluid comprises flowing the aqueous fluid through a centrifuge. The method further comprises placing the treated water in a first well bore of the well treatment operation. | 10-15-2009 |
| 20090260826 | METHOD AND SYSTEM FOR INJECTION OF VISCOUS UNWEIGHTED, LOW-WEIGHTED, OR SOLIDS CONTAMINATED FLUIDS DOWNHOLE DURING OILFIELD INJECTION PROCESS - A system for injecting a fluid into a formation including a fluid, and at least one injection pump configured to receive the fluid, the at least one pump including a centrifugal pump having at least two stages configured to increase the pressure of the received fluid is disclosed. The system further includes a drive device coupled to the injection pump. A method of injecting a fluid downhole including providing a fluid to an injection pump, the injection pump including a centrifugal pump having at least two stages, pumping the fluid through the at least two stages of the centrifugal pump, thereby increasing the pressure of the fluid, and injecting the fluid from the injection pump into a wellbore is also disclosed. | 10-22-2009 |
| 20090260827 | Enzyme enhanced oil recovery (EEOR) for water alternating gas (WAG) systems - The present disclosure relates to the release or recovery of subterranean hydrocarbon deposits and, more specifically, to a system and method for enhanced oil recovery (EOR), by utilizing enzyme compositions and water-alternating-gas (WAG) methods for injecting water compositions, followed by miscible, near miscible or immiscible gas into subterranean formations for oil recovery operations. | 10-22-2009 |
| 20090266546 | Apparatus and Method For Discharging Multiple Fluids Downhole - An apparatus and a method are provided for discharging a plurality of fluids downhole. In one aspect, the apparatus may include a first chamber and a second chamber separated by movable barrier, wherein draining the fluid from the first chamber causes the barrier to move and allow an actuating member to drain the second fluid from the second chamber. | 10-29-2009 |
| 20090266547 | Enzyme enhanced oil recovery (EEOR) for near wellbore treatment of oil and gas with greater than 50% barrel of oil equivalent (BOE) gas production - Disclosed is a system for injecting an enzymatic fluid composition into a gas or gas and oil near-well bore having a wide temperature range. The enzymatic fluid composition is a treatment for reducing oil deposits, asphaltenes, waxes, scale, or other hydrocarbon materials in a gas well or a combination gas/oil well where the production of gas is greater than 50% on a barrel of oil equivalent (BOE) basis. | 10-29-2009 |
| 20090277639 | Fluid Operated Well Tool - A well tool is operable to receive a flow of fluid. The well tool includes a first hydraulic area on which the fluid acts tending to move a first body to substantially seal against passage of fluid through an aperture. A second, larger hydraulic area is provided on which the fluid acts tending to move a second body. The second body is movable by the fluid acting on the second hydraulic to displace the first body from substantially sealing against passage of fluid through the aperture. An energy storing device is provided that is configured to store energy from movement of the second body until at least a specified amount of energy is stored and release the energy when the second body is moved to displace the first body from substantially sealing against passage of fluid through the aperture. | 11-12-2009 |
| 20090277640 | Methods of using a higher-quality water with an unhydrated hydratable additive allowing the use of a lower-quality water as some of the water in the forming and delivering of a treatment fluid into a wellbore - The inventions are for methods of forming and delivering a treatment fluid into a wellbore. In one aspect, methods are provided of using higher-quality water for one portion of the water for a treatment fluid and lower-quality water for another portion of the water for a treatment fluid, and merging the two portions to form the treatment fluid after pumping the fluid portions toward the wellbore. This allows the use of lower-quality water for some of the water required for making up the treatment fluid. | 11-12-2009 |
| 20090277641 | Methods of using a lower-quality water for use as some of the water in the forming and delivering of a treatment fluid into a wellbore - The inventions are for methods of forming and delivering a treatment fluid into a wellbore. In one aspect, methods are provided of treating a base aqueous solution to obtain a first aqueous solution, for example, to have a substantially reduced concentration of at least one component relative to the concentration of the component in the base aqueous solution, and using the first aqueous solution and a lower-quality water, such as the base aqueous solution, to form a treatment fluid. The first aqueous solution and the lower-quality water are merged after pumping the fluid portions toward the wellbore. The component is selected for being deleterious to the use or performance of a treatment fluid. More particularly, the component is selected from the group consisting of: a dissolved ion, oil, grease, a production chemical, and suspended, water-insoluble solids. This allows the use of lower-quality water for some of the water required for making up the treatment fluid. | 11-12-2009 |
| 20090308613 | METHOD AND APPARATUS TO TREAT A WELL WITH HIGH ENERGY DENSITY FLUID - The invention relates to methods and apparatuses for the subterranean injection of reactive substances like propellants into wellbores and subterranean reservoirs. These methods and apparatuses controls the temperature of a reactive substance for safe handling at surface and controls the decomposition rate of the substances in the subterranean environment. In addition, these methods and apparatuses provide a means for safe dilution of reactive fluids in the event of a leak or spillage of the reactive substance. | 12-17-2009 |
| 20090314493 | Method for controlled gelation of silicates - A process for forming a gel, which process comprises mixing an alkaline silicate solution with a polymer in solid form, the polymer being capable of being converted by hydrolysis into one or more organic acids; and allowing the polymer to release sufficient acid to cause formation of a silicate gel. | 12-24-2009 |
| 20100006292 | Methods and Systems for Determination of Fluid Invasion in Reservoir Zones - Methods and systems are described for stimulating a subterranean hydrocarbon-bearing reservoir, one method comprising contacting the formation with a treating fluid, and monitoring the movement of the treating fluid in the reservoir by providing one or more sensors for measurement of temperature and/or pressure which is disposed on a support adapted to maintain a given spacing between the sensors and the fluid exit. In some embodiments the support is coiled tubing. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims. | 01-14-2010 |
| 20100018711 | Tear Cord For Jacketed Tube - The disclosure pertains to installing a plurality of tear cords between a metal tube and a protective jacket. The multiple cords facilitate ease of removal of the protective jacket by creating a panel of the jacket that is detached from the remainder by pulling on the multiple tear cords. The resulting widened space can be used to remove the tube from the remaining protective jacket. The jacketed tubes may be used in a hydrocarbon production downhole well bore. The tubes may be used to furnish hydraulic fluid or chemicals into the well bore. The contents may be pressurized or under vacuum. The jacketed tubes are hermetically sealed. The tubes, which may be 1 inch in diameter, are joined using compression fittings. Tear cords are used to facilitate removal of the protective jacket without damage to the tube surface thereby facilitating the placement of compression fittings and maintaining the integrity of the tube wall. | 01-28-2010 |
| 20100032162 | FILL UP AND CIRCULATION TOOL AND MUDSAVER VALVE - A fill-up and circulation tool includes a mandrel; a packer assembly is disposed around the mandrel; and a valve assembly connected to the mandrel, wherein the valve assembly is configured to selectively control fluid flow into the tool and out of the tool. | 02-11-2010 |
| 20100051281 | Pneumatic Line Deicing System - A wellbore servicing method comprising supplying a deicing fluid to a pressurized pneumatic line on a drilling rig, whereby the deicing fluid retards the formation of ice within the pressurized pneumatic line is also disclosed. A wellbore servicing apparatus comprising a pump, a sight glass container coupled to the pump, and a storage tank coupled to the sight glass container and the pump is also disclosed. A wellbore servicing apparatus comprising an air regulator configured to couple to a pneumatic line coupled to an air compressor, a pneumatic pump coupled to the air regulator and configured to couple to the pneumatic line, a sight glass container coupled to the pneumatic pump, and a storage tank coupled to the sight glass container and the pneumatic pump is disclosed. | 03-04-2010 |
| 20100059225 | Flow Reversing Apparatus and Methods of Use - Apparatus and methods for selectively and safely reversing flow in coiled tubing used for wellbore cleanouts are disclosed. One apparatus includes a section of coiled tubing having a main flow channel, at least two flow-preventing valves in the section of coiled tubing, each adapted to close the main flow channel upon attempted flow reversal; and at least one actuator adapted to deter closing of the flow-preventing valves. This abstract allows a searcher or other reader to quickly ascertain the subject matter of the disclosure. It will not be used to interpret or limit the scope or meaning of the claims. 37 CFR 1.72(b). | 03-11-2010 |
| 20100186959 | Methods for treating a well by simultaneously introducing into a mixer streams of water, a viscosity-increasing agent, and a particulate and introducing the mixture into the well - A method is provided for treating at least a portion of a well. The method includes the steps of: (a) simultaneously introducing into a mixer at least: (i) a first stream comprising water; (ii) a second stream comprising a dry, hydratable, viscosity-increasing agent for water, wherein the second stream is substantially free of water; and (iii) a third stream comprising a non-hydratable, insoluble particulate; wherein at least the first and second streams are not mixed prior to being introduced into the mixer; (b) mixing the first, second, and third streams in the mixer to form a pumpable mixture, wherein: (i) the mixer creates at least a sufficiently-high shear rate to disperse the viscosity-increasing agent and the insoluble particulate in the pumpable mixture; and (ii) the pumpable mixture has or is capable of developing a substantially-higher viscosity than the viscosity of the first stream; and (c) introducing a treatment fluid comprising the pumpable mixture into a wellbore. | 07-29-2010 |
| 20100186960 | WELLBORE ANNULAR PRESSURE CONTROL SYSTEM AND METHOD USING ACCUMULATOR TO MAINTAIN BACK PRESSURE IN ANNULUS - A system for controlling wellbore annulus pressure during the drilling of a subterranean formation includes a drill string extending into a wellbore. A primary pump is configured for selectively pumping a drilling fluid through the drill string and into an annular space created between the drill string and the wellbore. A fluid discharge conduit is in fluid communication with the annular space for discharging the drilling fluid to a reservoir. A fluid back pressure system is connected to the fluid discharge conduit configured to selectively maintain pressure therein. The fluid back pressure system includes a fluid choke, a back pressure source and an accumulator hydraulically coupled between the back pressure source and the discharge conduit. | 07-29-2010 |
| 20100236783 | SITU EXTRACTION PROCESS FOR THE RECOVERY OF HYDROCARBONS - An in situ extraction process for the recovery of hydrocarbons from a hydrocarbon bearing formation, including the steps of injecting a solvent consisting substantially of one of the group of H2S, Ammonia or COS into the formation to mobilize the hydrocarbons for extraction by forming a mobile in situ extraction fluid; and lifting the extraction fluid containing the mobilized hydrocarbons from the underground formation to the surface. In a further aspect an extraction method for a specific reservoir is provided including the steps of: establishing a minimum desired extraction rate, based on a value for the porosity, permeability and dead oil viscosity of the in situ bitumen in the specific reservoir, determining a desired minimum operating extraction temperature determining a desirable range of operating pressures identifying solvents predicted to deliver the operating extraction temperature within the range of operating pressures, and selecting a preferred solvent to use in the process. | 09-23-2010 |
| 20100236784 | MISCIBLE STIMULATION AND FLOODING OF PETROLIFEROUS FORMATIONS UTILIZING VISCOSIFIED OIL-BASED FLUIDS - A viscosified miscible enhanced oil recovery fluid includes (a) a hydrocarbon fluid and viscosifying agent, wherein the viscosified fluid is a Newtonian fluid, (b) a hydrocarbon fluid and gelling agent, wherein the viscosified fluid is a power law fluid, (c) a hydrocarbon fluid, a gelling agent, and a rheological additive, wherein the viscosified fluid is a yield power law fluid, or (d) a hydrocarbon fluid, a gelling agent, a rheological additive, and solvent for the rheological additive, wherein the viscosified fluid is a yield power law fluid. The hydrocarbon fluid is preferably weighted with nano-scale weighting agents. The viscosified fluids are prepared and pumped into a subterranean petroliferous formation to recover a majority of the oil, heavy oil, condensate, or gas originally in place. A method for subsequently recovering a substantial fraction of the miscible injectant conventionally or by applying a viscosity breaker and recovering the viscosity-broken miscible injectant conventionally. | 09-23-2010 |
| 20100243254 | METHOD AND APPARATUS FOR ISOLATING AND TREATING DISCRETE ZONES WITHIN A WELLBORE - A method and apparatus for conducting a fracturing operation using a wellbore fracturing assembly. The assembly may be mechanically set and released from a wellbore using a coiled tubing string to conduct a fracturing operation adjacent an area of interest in a formation. The assembly may include an unloader for equalizing pressure between the assembly and the wellbore, a pair of spaced apart packers for straddling the area of interest, an injection port disposed between the packers for injecting fracturing fluid into the area of interest, and an anchor for securing the assembly in the wellbore. After conducting the fracturing operation, the assembly may be relocated to another area of interest to conduct another fracturing operation. | 09-30-2010 |
| 20100263870 | METHODS OF CONTACTING AND/OR TREATING A SUBTERRANEAN FORMATION - Methods of contacting a subterranean formation are described which provide improved control or reduction of particulate migration, transport or flowback in wellbores and reservoirs, and which may do so without sacrificing substantial hydraulic conductivity. One method comprises injecting into a well-bore intersecting the subterranean formation a fluid composition comprising a first component and a second component dispersed in a carrier fluid, at least a portion of the first component or second component being provided as at least one multicomponent article having an aspect ratio greater than 1:1.1; forming a network comprising the first component; and binding the network with the second component. | 10-21-2010 |
| 20100270019 | METHOD OF OBTAINING A TREATMENT COMPOSITION FOR IMPROVING THE PRODUCTIVITY OF HYDROCARBON PRODUCING WELLS - A method of obtaining a treatment composition for treating a hydrocarbon-bearing clastic formation having brine therein to enhance recovery of hydrocarbon from the formation. The method comprises: obtaining a formation information set comprising a temperature value, brine content value, and brine composition data obtained from a geological zone of the hydrocarbon-bearing clastic formation; comparing the formation information set to a compatibility information set to generate a comparison information set, the compatibility information set comprising compatibility information for at least at least one model brine and at least one model composition at least one model temperature; selecting a treatment composition based, at least in part, on the at least one comparison information set, wherein the treatment composition comprises a second surfactant dissolved in a second solvent; and obtaining the treatment composition for treating the hydrocarbon-bearing clastic formation to enhance recovery of hydrocarbon from the formation. | 10-28-2010 |
| 20100270020 | METHODS FOR TREATING HYDROCARBON-BEARING FORMATIONS WITH FLUORINATED ANIONIC SURFACTANT COMPOSITIONS - Methods of treating a hydrocarbon-bearing formation having brine and liquid hydrocarbons and treated hydrocarbon-bearing formations. The methods include contacting the hydrocarbon-bearing formation with a composition comprising solvent and a fluorinated anionic surfactant. In some embodiments, the solvent solubilizes the brine in the hydrocarbon-bearing formation without causing the fluorinated anionic surfactant to precipitate. In some embodiments, the solvent includes at least one of a polyol or polyol ether independently having from 2 to 25 carbon atoms and at least one of water, a monohydroxy alcohol, an ether, or a ketone, wherein the monohydroxy alcohol, the ether, and the ketone each independently have up to 4 carbon atoms. | 10-28-2010 |
| 20100270021 | METHODS FOR TREATING HYDROCARBON-BEARING FORMATIONS WITH FLUORINATED POLYMER COMPOSITIONS - A method of treating a hydrocarbon-bearing formation and treated hydrocarbon-bearing formations. The method includes contacting the hydrocarbon-bearing formation with a composition having solvent and a fluorinated polymer. The fluorinated polymer has units having formula (I): A method for making a composition containing these units is also disclosed. | 10-28-2010 |
| 20100276149 | Method for Treating a Hydrocarbon Formation - The present invention includes compositions and method for treating a hydrocarbon-bearing clastic formation having brine, the method comprising: contacting the hydrocarbon-bearing clastic formation with a fluid, wherein the fluid at least one of at least partially solubilizes or at least partially displaces the brine in the hydrocarbon-bearing clastic formation; and subsequently contacting the hydrocarbon-bearing clastic formation with a composition, the composition comprising: a nonionic fluorinated polymeric surfactant, and solvent, wherein when the composition is contacting the hydrocarbon-bearing clastic formation, the nonionic fluorinated polymeric surfactant has a cloud point that is above the temperature of the hydrocarbon-bearing clastic formation. | 11-04-2010 |
| 20100276150 | PROVISION OF VISCOUS COMPOSITIONS BELOW GROUND - A thickened aqueous composition is delivered to a subterranean location accessible via a wellbore by steps of i. providing a biphasic aqueous mixture comprising two aqueous solutions which, at surface temperature and pressure, are able to co-exist as separate aqueous phases in contact with each other, ii. pumping said biphasic aqueous system down the wellbore to the subterranean location, and iii. converting the biphasic mixture below ground so that its phases combine into a single aqueous phase which is more viscous than the biphasic mixture. The two phases of the aqueous biphasic mixture contain dissolved solutes which segregate between the two phases such that at least one first solute is present at a greater concentration in the first aqueous phase than in the second aqueous phase while at least one second solute is present at a greater concentration in the second aqueous phase than in the first aqueous phase. The solute in the first phase may be a thickening polymer or other thickening material such as viscoelastic surfactant. The solute in the second phase may be a different polymer, surfactant or salt. Conversion to a single phase may be carried out in various ways including dilution, change in pH, change in salinity, increase in temperature and adsorption of one solute onto formation rock. | 11-04-2010 |
| 20100282467 | Sulfonated internal olefin surfactant for enhanced oil recovery - A process for recovering oil from an oil-bearing formation comprises introducing into said formation an aqueous composition comprising at least one sulfonated derivative of one or more internal olefins, said internal olefins being characterized by having low amounts of tri-substitution on the olefin bond, said sulfonated derivative being obtained by sulfonating a composition comprising internal olefins of the formula: | 11-11-2010 |
| 20100282468 | FRACTURING FLUID COMPOSITIONS COMPRISING SOLID EPOXY PARTICLES AND METHODS OF USE - Fluid compositions and methods of making and using same are described, the fluid compositions comprising at least one solid epoxy particle, at least one epoxy resin curing agent, and at least one type of proppant particles. The methods comprise deploying a fluid composition into a wellbore extending to a subterranean geological formation using pressure sufficient to form a fracture in the subterranean geological formation, and immobilizing at least a portion of the solid epoxy particles and proppant particles in the fracture. Embodiments of the fluid compositions are useful for increasing hydrocarbon production from subterranean geologic formations, and/or controlling solids migration in such formations. | 11-11-2010 |
| 20100288498 | FLUORINATED POLYMER COMPOSITIONS AND METHODS FOR TREATING HYDROCARBON-BEARING FORMATIONS USING THE SAME - Fluorinated polymers having first divalent units represented by formula, and a plurality of groups of formula —CH | 11-18-2010 |
| 20100294497 | Recovery of oil - A method of recovering oil from a subterranean formation which includes an association production well involves contacting oil in the formation with a treatment fluid formulation which includes polyvinylalcohol and collecting oil which is being contacted with said treatment fluid formulation by said production well. Use of the polyvinylalcohol, optionally in combination with other materials, facilities recovery of oil from subterranean formation, particularly those involving medium or high viscosity oils. | 11-25-2010 |
| 20100294498 | VISCOELASTIC SURFACTANT BASED WELLBORE FLUIDS AND METHODS OF USE - A wellbore fluid that includes an aqueous based fluid; an amphoteric, viscoelastic surfactant; and a modified starch is disclosed. Methods of drilling subterranean wells, methods of reducing the loss of fluid out of subterranean wells, and methods of completing wellbores using aqueous-based fluids having an ampoteric, viscoelastic surfactant and a modified starch are also disclosed. | 11-25-2010 |
| 20100294499 | OIL RECOVERY EMPLOYING ALKYLENE CARBONATES - The present invention discloses an enhanced oil recovery method that contacts a gas and an alkylene carbonate with a subterranean formation. | 11-25-2010 |
| 20100300692 | APPARATUS AND METHODS FOR LIMITING DEBRIS FLOW BACK INTO AN UNDERGROUND BASE PIPE OF AN INJECTION WELL - In some embodiments, apparatus for assisting in reducing flowback of debris from an earthen formation into an underground fluid injection system includes a screen member disposed around and longitudinally moveable relative to a base pipe and shielded from direct contact with fluid as it is ejected from the base pipe. | 12-02-2010 |
| 20100307752 | Fluid Treatment Systems, Compositions and Methods for Metal Ion Stabilization in Aqueous Solutions and/or Enhanced Fluid Performance - Fluid treatment systems and compositions are provided including (a) at least one material including (1) at least one carboxylic acid functional group and (2) at least one sulfur-containing group selected from the group consisting of sulfonyl functional groups, sulfonate functional groups and mixtures thereof; and (b) at least one friction reducing agent selected from the group consisting of guar gums, polyacrylamides, hydratable cellulosic materials, viscoelastic surfactants, and mixtures thereof. The fluid treatment systems and compositions can be used to treat aqueous systems, for example as fracturing fluids for use in fracturing subterranean formations. Methods for inhibiting formation and/or precipitation of metal oxides in an aqueous composition using the fluid treatment systems or compositions also are provided. | 12-09-2010 |
| 20100307753 | Methods of Treating Flowback Water - Methods of treating flowback water from a subterranean formation penetrated by a well bore are provided, comprising: (a) providing remediated flowback water having a ferrous iron (Fe | 12-09-2010 |
| 20100307754 | Aerosol injection into vadose zone - An apparatus and process for delivering aerosol-based amendments into a subsurface region is provided. The apparatus used to form the aerosol has an ability to restrict the aerosol particle size to a preferred particle size range such that undesired particle sizes are not introduced. By maintaining a proper ratio of aerosol particle size to subsurface pore size, the efficiency of an aerosol introduction can be enhanced. | 12-09-2010 |
| 20100314114 | SWELLABLE POLYMER WITH ANIONIC SITES - The invention is directed to stable crosslinked water-soluble swellable polymers and methods for making same. More particularly, the invention relates to a composition comprising expandable polymeric particles having anionic sites and labile crosslinkers and stable crosslinkers, said particle mixed with a fluid and a cationic crosslinker that is capable of further crosslinking the particle on degradation of the labile crosslinker and exposure of the anionic sites so as to form a gel. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into target zone and when the heat and/or suitable pH of the target zone cause degradation of the labile crosslinker and the particle expands, the cationic crosslinker crosslinks the polymer to form a gel, thus diverting water to lower permeability regions and improving oil recovery. | 12-16-2010 |
| 20100314115 | SWELLABLE POLYMER WITH CATIONIC SITES - The invention is directed to long lasting crosslinked water-soluble swellable polymers, methods for making same, and their uses. More particularly, the invention relates to a composition comprising expandable polymeric particles having cationic sites as well as labile crosslinkers and stable crosslinkers, said particle mixed with a fluid. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into a target zones in the reservoirs and when the heat and/or a suitable pH in the reservoir cause degradation of the labile crosslinker and when the particle expands, the cationic sites in the polymer adsorb to negative sites of the rock in the formation, thus diverting water to lower permeability regions and improving oil recovery. However, many other uses are possible. | 12-16-2010 |
| 20100314116 | Method of Removing Inorganic Scales - The productivity of hydrocarbons from hydrocarbon-bearing calcareous or siliceous formations is enhanced by contacting the formation with a well treatment composition which contains a hydrofluoric acid source, a boron containing compound and a phosphonate acid, ester or salt thereof. | 12-16-2010 |
| 20100319921 | WELLBORE FLUID MIXING SYSTEM - A system for mixing fluids for oilfield applications, the system including a first storage vessel ( | 12-23-2010 |
| 20100326661 | WELL JET DEVICE AND THE OPERATION METHOD THEREOF - Well jet enables forming, via jet pump, range of different depressions in well tail area at specified differential pressure value. Logging instrument enables recording well and pumped out medium physical parameters. Well operating modes are adjusted by spring-loaded stepped piston positioned in seal unit body so as to open and close holes. Return valves in pumped out and active media supply channels, combined with stepped through channel, of diameter equal to or greater than diameter of the axial through hole of a packer and which is made in the pump body below a mounting seat, enable supplying chemical reagents along a pipe string to a production formation without additional units and prevent media pumped to the production formation, from annular above-packer space penetration. Said invention enables increasing reliability and performance by preventing active medium backflow and by maintaining the depression produced on the formation when the jet pump is stopped. | 12-30-2010 |
| 20100326662 | Viscous Oil Recovery Using Emulsions - The present invention is directed to a method of generating a basic water-in-oil emulsion for use in recovering hydrocarbons from a subterranean formation. The emulsion may be used to displace hydrocarbons from the formation. The emulsions used are ‘basic’ in the sense that they do not have added surfactants and are not solid-stabilized. The emulsions are made using a hydrocarbon having at least one of the following properties: (i) greater than five weight percent (wt %) asphaltene content, (ii) greater than two wt % sulfur content, and (iii) less than 22 dyne/cm interfacial tension between the hydrocarbon liquid and the aqueous liquid. | 12-30-2010 |
| 20110000671 | Low Emission Power Generation and Hydrocarbon Recovery Systems and Methods - Methods and systems for low emission power generation in hydrocarbon recovery processes are provided. One system includes integrated pressure maintenance and miscible flood systems with low emission power generation. The system may also include integration of a pressure swing reformer (PSR), air-blown auto-thermal reformer (ATR), or oxygen-blown ATR with a gas power turbine system, preferably a combined cycle gas power turbine system. Such systems may be employed to capture and utilize greenhouse gases (GHG) and generate power for use in hydrocarbon recovery operations. | 01-06-2011 |
| 20110005758 | METHOD AND COMPOSITION FOR CURING LOST CIRCULATION - The invention provides a system made of fibers and a material able to stick fibers in a network when activated, such activation can be temperature or pH change. The invention preferably is used in a well and as a method to cure lost circulation. | 01-13-2011 |
| 20110011589 | Well Service Compositions for Consolidation of Particulates in Subterranean Coal Seams - A method of agglomerating coal particles in a subterranean formation having a coal seam, comprising the steps of providing (a) a fluid having an aqueous medium and a first collector and/or a frother; (b) pumping the fluid into the formation and (c) contacting coal particles in the formation thereby agglomerating the contacted coal particles. | 01-20-2011 |
| 20110011590 | USE OF AUTONOMOUS (SELF-ADJUSTING) VALVES IN INJECTORS IN OIL PRODUCTION - A method for injecting a fluid into an oil and or gas reservoir or formation, in which the fluid flows into the reservoir or formation through a plurality of autonomous valves or flow control devices ( | 01-20-2011 |
| 20110011591 | TEMPORARY FLUID DIVERSION AGENTS FOR USE IN GEOTHERMAL WELL APPLICATIONS - Systems, methods and compositions for temporary sealing fractures in subterranean formations are herein disclosed. According to one embodiment, a composition comprising at least one constituent for temporary sealing a fracture in a subterranean well is provided. The degradation kinetics of the composition is dependent upon at least one degradation temperature-time parameter for designating a temperature range and a time at which the composition degrades. | 01-20-2011 |
| 20110017456 | Method and Device for Feeding Liquefied Carbon-Dioxide Gas into an Aquifer Deep Underground - To provide a method and device for feeding liquefied carbon-dioxide gas into the ground, by which liquefied carbon-dioxide gas can be efficiently permeated and diffused in a deep aquifer. The present invention's method for feeding liquefied carbon-dioxide gas into the ground includes the following steps: using a pumping well to pump up water from a deep aquifer to aboveground; creating injection water; applying pulsatile hydraulic pressure to the injection water; feeding the injection water to which pulsatile hydraulic pressure has been applied into the deep aquifer via an injection well; feeding liquefied carbon-dioxide gas—while maintaining said gas in a liquefied condition—from a storage tank into the injection well to a depth having such pressure and temperature in which the liquefied condition can be maintained; mixing the liquefied carbon-dioxide gas—in the form of fine droplets—with the injection water, thereby generating a mixture of those two liquids. | 01-27-2011 |
| 20110017457 | ENVIRONMENTAL COMPOSITIONS AND METHODS FOR WELL TREATMENT - The invention provides a well treatment composition comprising: a viscoelastic surfactant or a cementing composition and an environmentally friendly component made of cellulosic matrix with organic acid trapped within. A method is disclosed comprising introducing into a wellbore penetrating a subterranean formation an environmentally friendly component made of cellulosic matrix with organic acid trapped within. | 01-27-2011 |
| 20110030956 | ALTERING THE INTERFACE OF HYDROCARBON-COATED SURFACES - Methods and compositions are provided wherein microorganisms are used to alter the interface of hydrocarbons and hydrocarbon-coated surfaces to increase oil recovery, for improved bioremediation and/or pipeline maintenance. | 02-10-2011 |
| 20110030957 | CARBON CAPTURE AND STORAGE - Aspects of the invention include methods of contacting carbon dioxide with an aqueous mixture. In practicing methods according to certain embodiments, a subterranean brine may be contacted with carbon dioxide to produce a reaction product, which may or may not be further processed as desired. Also provided are methods in which a brine or minerals are contacted with an aqueous composition. Aspects of the invention further include compositions produced by methods of the invention as well as systems for practicing methods of the invention. | 02-10-2011 |
| 20110030958 | METHOD FOR TREATING SUBTERRANEAN FORMATION WITH DEGRADABLE MATERIAL - A method is for treating a subterranean formation penetrated by a wellbore is given which comprises providing a treatment fluid comprising a viscoelastic surfactant having at least one degradable linkage, a hydrolysable material, and a pH control material, wherein the pH control material has a pH equal or greater than about 9 and comprises a strongly alkaline material and an oxidizing agent; and injecting into the subterranean formation the treatment fluid. | 02-10-2011 |
| 20110030959 | Aqueous Solution For Managing Microbes In Oil And Gas Production And Method For Their Production - This invention relates to compositions for the management and treatment of water used for the production of oil and gas products comprising an electro-chemically activated, cation or anion-containing aqueous solution (catholyte or anolyte), and to a system and process for their production. A plant is described for treating water used for petroleum production and products including a water reservoir ( | 02-10-2011 |
| 20110030960 | METHODS AND APPARATUS FOR A DOWNHOLE TOOL - An apparatus and method for operating a packer and a fracture valve is shown. The packer may include a tubular mandrel having a longitudinal bore with an annular packing element and a first piston disposed around the mandrel, wherein the first piston is operable to set the packing element, and a second piston operable to isolate fluid communication between the first piston and the mandrel bore. The fracture valve may include a tubular mandrel having a longitudinal bore and a port, a piston operable to close fluid communication between the bore and the port, and a latch disposed between the piston and the mandrel operable to resist movement of the piston. | 02-10-2011 |
| 20110036577 | MANIPULATION OF FLOW UNDERGROUND - Solid material required at a subterranean location is supplied from the surface suspended in a carrier liquid and agglomerated below ground by means of a binding liquid. Agglomeration is achieved by arranging that the binding liquid and the particulate solid are similar to each other but opposite to the carrier liquid in hydrophilic/hydrophobic character. The solid and the binding liquid may both be hydrophobic while the carrier liquid is hydrophilic, or vice versa. The solid may be hydrophobically surface modified to render it hydrophobic. The binding liquid may be provided as a precursor which converts to the binding liquid below ground to trigger agglomeration after arrival at the subterranean location. | 02-17-2011 |
| 20110036578 | Apparatus and Method for Passive Fluid Control in a Wellbore - In aspects the present disclosure provides systems, devices and methods for controlling the flow of water from a subterranean formation into a production well. In one embodiment, the device may include a flow control member formed from a shape-conforming material and a hydrophilic polymer disposed within the shape-conforming member in an amount sufficient to cause the flow control member to restrict flow of water therethrough. | 02-17-2011 |
| 20110036579 | Water-Based Mud Lubricant Using Fatty Acid Polyamine Salts and Fatty Acid Esters - Water-based drilling mud lubricants using a blend of fatty acid polyamine salts and fatty acid esters give synergistically better lubricity results than either component used separately. For example, the blends with different ratios of fatty acid diethylenetriamine salt and fatty acid methyl ester demonstrate much better lubricity in water-based drilling fluids than those where only fatty acid diethylenetriamine salt or fatty acid methyl ester are separately used. The amines in fatty acid amine salt might also include other polyamines, such as butanediamine pentamethylenediamine, spermidine, spermine, propylene diamine and propylene polyamines. The fatty acid esters might also include fatty acid ethyl ester, fatty acid glycerol ester and fatty acid trimethylolpropane ester. The carbon numbers of the fatty acids used to make the components in the lubricant blend may range from C4 to C28. | 02-17-2011 |
| 20110036580 | OIL RECOVERY BY SEQUENTIAL WATERFLOODING WITH OIL REINJECTION AND OIL RELOCATION - A method for enhancing oil recovery from reservoirs is described. The method includes partially recharging zones of pore space in a reservoir that has been previously waterflooded to extract oil, in order to obtain increased ultimate oil recovery by re-waterflooding the recharged zones. The recharging may be achieved by either reinjection of oil or by change in injection scheme, such as changing an oil producing well to a water injection well. This procedure of recharging with oil followed by waterflooding may be repeated. Application of the present method to increase recovery from reservoirs producing dry (water-free) oil to mature reservoirs which produce at high water-to-oil ratios is anticipated. | 02-17-2011 |
| 20110036581 | SYSTEM FOR PULSE-INJECTING FLUID INTO A BOREHOLE - For injecting e.g. water into ground formation around a borehole, and for superimposing pulses onto the outflow of the injected water, it is important that the pulses have a rapid rise-time. A piston is connected to a pulse-valve of the tool. A bias spring urges the piston towards its closed position. The piston is urged towards the open position by a differential PDAF between the supplied accumulator-pressure and the in-ground formation-pressure. When the pulse-valve is open, the PDAF is falling, until the force of the spring closes the pulse-valve. Then the PDAF rises, but now the PDAF acts over only a small area of the piston. When the PDAF is high enough to ease the pulse-valve open, suddenly the whole area of the piston is exposed to the PDAF, whereby the pulse-valve opens violently. | 02-17-2011 |
| 20110042090 | COMPOSITE MICRO-COIL FOR DOWNHOLE CHEMICAL DELIVERY - A technique utilizes micro-coil which is formed as a composite to enable use at substantial depths and/or with substantial flow rates. The micro-coil is formed as a tubing with a multi-layered tubing wall. The composite tubing wall provides substantial strength and longevity which allows deployment of the micro-coil in a much wider variety of well treatment applications, such as applications having substantial flow rates and/or applications at substantial well depths. | 02-24-2011 |
| 20110048718 | Treatment Fluids Comprising Entangled Equilibrium Polymer Networks - The invention relates to compositions and methods relating to treatment fluids that comprise entangled equilibrium polymer networks in subterranean applications. In one aspect, the invention provides a method comprising: providing a treatment fluid comprising at least one entangled equilibrium polymer network, and placing the treatment fluid in a subterranean formation. | 03-03-2011 |
| 20110048719 | RATE INDUCED DIVERSION FOR MULTI-STAGE STIMULATION - The invention provides a method of stimulation a subterranean formation to improve formation fluid production, the method comprising: providing a wellbore which penetrates the subterranean formation, wherein the wellbore comprises at least two perforation cluster zones; injecting a treatment fluid into the wellbore at a fluid pressure equal to or greater than the fracture initiate pressure of the subterranean formation; contacting the subterranean formation with the treatment fluid through a first perforation cluster zone; performing a shutin by stopping injection of the treatment fluid; waiting for a determined period of time, wherein no physical material is introduced into the wellbore and no significant reverse flow from the subterranean formation to the wellbore occurs during said period of time; resuming the introduction of the treatment fluid into the wellbore at a fluid pressure equal to or greater than the fracture initiate pressure of the subterranean formation; and contacting the subterranean formation with the treatment fluid through a second perforation cluster zone. | 03-03-2011 |
| 20110056692 | SYSTEM FOR COMPLETING MULTIPLE WELL INTERVALS - A system includes a string that comprising a passageway and a plurality of tools. The system further includes an untethered object that is adapted to be deployed in the passageway such that the object travels downhole via the passageway and controllably expand its size as the object travels downhole to selectively cause one of the tools to capture the object. | 03-10-2011 |
| 20110067874 | Method of redistributing well bore fluid - Redistribution of fluids present in well bore environments is disclosed. In some embodiments, the invention may be the redistribution of water produced in a coal bed methane well. The redistribution of water from one aquifer ( | 03-24-2011 |
| 20110073311 | PUMPABLE GEOPOLYMER FORMULATION FOR OILFIELD APPLICATION - The invention provides geopolymeric compositions, which have controllable thickening and setting times for a wide range of temperatures and a large range of geopolymer slurry densities. The geopolymer slurry compositions have good mixability and pumpability, whilst the set materials develop good compressive strength and permeability. The invention discloses a method for preparing geopolymer for oilfield cementing applications. The geopolymeric compositions according to the invention comprises a suspension made of an aluminosilicate source, a carrier fluid, an activator taken from the list constituted by: a metal silicate, a metal aluminate, an alkali activator, or a combination thereof, and an aluminum containing compound taken in the list constituted of bauxite, aluminum oxide and aluminum salt and the suspension is a pumpable composition in oilfield industry and the suspension is able to set under well downhole conditions. | 03-31-2011 |
| 20110100629 | Methods of Using Hydrocarbon Gelling Agents as Self-Diverting Scale Inhibitors - Method of treating a subterranean formation using a hydrocarbon treatment fluid using a phosphor-based hydrocarbon gelling agent that is capable of both increasing the viscosity of the hydrocarbon treatment fluid and remaining in the subterranean formation after the viscosity of the gel is broken such that it can act as a scale inhibitor. Phosphor-based hydrocarbon gelling agents formed from a polyvalent metal salt of an organophosphonic acid ester or from a polyvalent metal salt of an organophosphinic acid are described. | 05-05-2011 |
| 20110100630 | Method of Mitigating Corrosion Rate of Oilfield Tubular Goods - Acid-soluble cupric acetate may used in conjunction with potassium iodide to generate cuprous iodide (CuI) as an acid corrosion inhibition aid. A suitable corrosion inhibitor together with the aid protects steel surfaces in an acid environment, for instance, while acid fracturing or matrix acidizing subterranean formations. Cupric acetate monohydrate may be used with an alkali metal iodide salt such as potassium iodide or sodium iodide to generate cuprous iodide in situ in aqueous acid solutions. Use of cupric acetate provides a somewhat delayed reaction rate with potassium iodide to generate the desired product, cuprous iodide, which has very low solubility in acid systems. The method includes delayed and in situ production of cuprous iodide for enhancing performance of commercially available corrosion inhibitors, commonly referred to as intensifying the effect of the corrosion inhibitor (corrosion inhibitor intensifier or simply an intensifier). | 05-05-2011 |
| 20110100631 | FLOODING FLUID AND ENHANCING OIL RECOVERY METHOD - The invention relates to an enhancing oil recovery method by injecting into a subterranean oil formation an aqueous flooding fluid comprising at least one injecting galactomannan polymer substituted by at least one sulfonation agent. The invention also relates to an flooding fluid having better injectivity properties than existing flooding fluids. | 05-05-2011 |
| 20110100632 | METHOD FOR MONITORING FLOOD FRONT MOVEMENT DURING FLOODING OF SUBSURFACE FORMATIONS - This invention relates generally to methods for monitoring directional flood front movement during oil recovery and more specifically to methods for monitoring flood front movement of flooding agent injected into subsurface formations. The method comprises detecting physical properties of subsurface formation and injection of a flooding agent into said formation through at least one injection well thus forcing reservoir oil movement toward at least one production well. The flooding agent is a highly dispersed gas-liquid mixture having size of gas bubbles not exceeding an average diameter of the pores of said oil-bearing reservoir. The method further comprises detecting the same physical properties of the formation at the same area after flooding and monitoring the flood front profile by registrating changes in the physical properties of the formation caused by the arrival of said flood front. | 05-05-2011 |
| 20110114318 | Compositions and systems for combatting lost circulation and methods of using the same - A method of servicing a wellbore in a subterranean formation comprising preparing a composition comprising a base fluid, a thixotropic viscosifier, a gellable composition and a bridging material, applying a shear force to the composition such that the composition viscosity decreases, introducing the composition into a lost circulation zone in the subterranean formation, wherein the lost circulation zone comprises cavities greater than about 200 microns in diameter, decreasing the shear force applied to the composition, and allowing the composition to set in the lost circulation zone. A method of servicing a wellbore in a subterranean formation comprising placing a first stream comprising a dilute solution of a metal acrylate into a lost circulation zone in the subterranean formation, placing a second stream comprising an activator into the lost circulation zone, and forming a lost circulation material upon contacting of the metal acrylate and the activator, wherein the lost circulation material forms in from about 0 to about 60 minutes. | 05-19-2011 |
| 20110120717 | GENERATION OF FLUID FOR HYDROCARBON RECOVERY - Methods and apparatus relate to recovering petroleum products from underground reservoirs. The recovering of the petroleum products relies on introduction of heat and solvent into the reservoirs. Supplying water and then solvent for hydrocarbons in direct contact with combustion of fuel and oxidant generates a stream suitable for injection into the reservoir in order to achieve such thermal and solvent based recovery. | 05-26-2011 |
| 20110127037 | Method and System for Methanol Production - An apparatus and method of producing methanol includes reacting a heated hydrocarbon-containing gas and an oxygen-containing gas in a reactor; to provide a product stream comprising methanol; and transferring heat from the product stream to the hydrocarbon-containing gas to heat the hydrocarbon containing gas. After removing methanol and CO | 06-02-2011 |
| 20110132610 | CERAMIC MICROSPHERES FOR CEMENTING APPLICATIONS - A method and apparatus for manufacturing ceramic microspheres from industrial slag. The microspheres have a particle size of about 38 microns to about 150 microns. The microspheres are used to create a cement slurry having a density of at least about 11 lbs/g. The resultant cement slurry may then be used to treat subterranean wells. | 06-09-2011 |
| 20110139454 | Method for Providing Thixotrophy to Fluids Downhole - A method of providing thixotropy to a fluid downhole comprising: adding an encapsulated thixotropic agent to a fluid at the surface; introducing the fluid into a borehole; and subjecting the fluid to a shearing action so as to release the thixotropic agent into the fluid. | 06-16-2011 |
| 20110139455 | STORING DEVICE FOR STORED SUBSTANCE AND METHOD FOR STORING STORED SUBSTANCE | 06-16-2011 |
| 20110146992 | Controllable Chemical Injection For Multiple Zone Completions - This disclosure relates to an apparatus and method for controlling the amount of an additive injected into production fluid in a plurality of production zones. The injection devices may be dynamically controlled such that a central or decentralized control system may instruct a plurality of additive injection assemblies to inject additive, wherein different additive and/or different amounts of additive may be injected in the production fluid in the plurality of production zones. The apparatus includes one or more controllers to send operating commands to downhole regulating elements that may control the amount of additive being injected directly or indirectly. | 06-23-2011 |
| 20110146993 | SYSTEM AND METHOD FOR WATERFLOODING OFFSHORE RESERVOIRS - A mobile water injection system and method for performing waterflooding in offshore reservoirs, and more particularly to enhance oil recovery in marginal offshore reservoirs is disclosed. The mobile water injection system and method include portable equipment, including a submersible pump to recover water from a body of water, a water storage tank, filtration and chemical treatment equipment to treat the recovered water, and an injection pump to pump the treated water at high pressure into the reservoir such that the residual oil is driven to adjacent production wells to increase oil recovery. | 06-23-2011 |
| 20110155376 | DELIVERING WATER-SOLUBLE POLYSACCHARIDES FOR WELL TREATMENTS - A method is provided comprising the steps of: (a) providing a dispersion comprising: a water-soluble polysaccharide and a carrier fluid, wherein the carrier fluid comprises: (i) glycerol, and (ii) a mono-hydroxylic alcohol having 1-3 carbons, wherein the mono-hydroxylic alcohol is present in at least 0.1% by weight of the glycerol, wherein the polysaccharide is insoluble in the carrier fluid; (b) mixing the dispersion with at least water to form an aqueous well treatment fluid, wherein the polysaccharide is soluble in the aqueous phase of the aqueous wellbore treatment fluid; and (c) introducing the aqueous treatment fluid into a subterranean formation. | 06-30-2011 |
| 20110162848 | Fluid Injection Completion Techniques - Methods for injecting a fluid into a subsurface formation are provided. Each of the methods includes the obtaining data, including formation parameters and operational variables, related to an injection well. A regime of operation for the injection well is determined. The regime of operation is determined using a heuristic model. In one aspect, one or more operational variables, including completion design, reservoir development procedures, and/or injection procedures, is designed based at least in part on the determined regime of operation. Water or other fluid may then be injected into the subsurface formation. The step of determining the regime of operation for the injection well may use a full physics computational simulation to construct a mathematical model that can estimate the operating regime for the water injection well. Alternatively or in addition, field data may be used. | 07-07-2011 |
| 20110168395 | Methods of Fluid Loss Control and Fluid Diversion in Subterranean Formations - Improved methods of placing and/or diverting treatment fluids in subterranean formations are described. The methods include introducing a treatment fluid into a subterranean formation penetrated by a wellbore, wherein the treatment fluid comprises: a base fluid, and a plurality of solid particulates comprising at least one selected from the group consisting of: a scale inhibitor, a chelating agent, and a combination thereof, wherein the solid particulates are substantially insoluble in the base fluid; and allowing at least a portion of the solid particulates to form a barrier or at partially divert a subsequent fluid. | 07-14-2011 |
| 20110174488 | ACCELERATED START-UP IN SAGD OPERATIONS - A method of initiating or accelerating the establishment of fluid communication between horizontal wells located in a formation of very limited fluid mobility, such as an oil sand at original temperature or an infill well completed in an immobile hydrocarbon region located between surrounding well patterns in which a gravity-dominated recovery process is or has been operated. | 07-21-2011 |
| 20110174489 | FRACTURING/GRAVEL PACKING TOOL SYSTEM WITH DUAL FLOW CAPABILITIES - A fracturing/gravel packing tool system with dual flow capabilities. A method of treating a well includes the steps of: flowing a fluid into the well through a work string while simultaneously flowing another fluid into the well through an annulus; and directing each of the fluids to the exterior of a well screen in the well. A well treatment system includes a slurry and a fluid flowed into a well. The slurry has an initial density, but the fluid is mixed with the slurry in the well, thereby causing the slurry to have a reduced density in the well. Another method of treating a well includes the steps of: installing a gravel packing assembly including a well screen in the well; flowing a slurry and a fluid into the well; mixing the slurry with the fluid, thereby reducing a density of the slurry in the well; and flowing the reduced density slurry about an exterior of the well screen. | 07-21-2011 |
| 20110198086 | Hydrate Control In A Cyclic Solvent-Dominated Hydrocarbon Recovery Process - The present invention relates generally to in situ hydrate control during hydrocarbon production when applying a recovery method utilizing cyclic injection of light hydrocarbon solvents. Hydrate formation is limited by creating an energy reserve within a hydrocarbon reservoir adjacent to the wellbore. A heated solvent is injected during an injection phase of a cyclic solvent dominated recovery process to form a heated region adjacent to the wellbore at the end of an injection cycle. The energy reserve is used to act against the evaporative cooling effect caused by subsequent production and associated depressurization to maintain reservoir conditions outside of hydrate formation conditions. In situ conditions are estimated and injected energy amounts are controlled. | 08-18-2011 |
| 20110220359 | Methods Relating to Modifying Flow Patterns Using In-Situ Barriers - A method comprises providing a fluid source in a subterranean formation; providing a wellbore in the subterranean formation; and providing an in-situ barrier, wherein the in-situ barrier is disposed within the subterranean environment and modifies the flow pattern of at least one fluid within the subterranean formation that is provided by the fluid source and flows towards the wellbore. | 09-15-2011 |
| 20110220360 | APPLICATION OF ALKALINE FLUIDS FOR POST-FLUSH OR POST-TREATMENT OF A STIMULATED SANDSTONE MATRIX - Apparatus and method for treating a subterranean formation including forming a first fluid comprising low pH, introducing the first fluid into a subterranean formation, forming a second fluid comprising high pH, and introducing the second fluid into the formation. Apparatus and method for treating a subterranean formation including introducing a acidizing fluid into a subterranean formation, introducing an inert spacer into the formation, introducing an alkaline fluid into the formation, and introducing a brine or a solvent overflush fluid. | 09-15-2011 |
| 20110226479 | DIVERSION BY COMBINING DISSOLVABLE AND DEGRADABLE PARTICLES AND FIBERS - In downhole treatments in the oilfield, ball sealers seated in perforations may not fully seal and may leak fluid through gaps and asperities between the balls and the perforations. A method is given for improving the sealing of ball sealers in perforations by adding a sealing agent that forms a plug in the gaps and severely restricts or eliminates fluid flow. The sealing agent is preferably degradable or soluble, malleable fibers slightly larger than the gaps. Optionally, the particles may be non-degradable, rigid, of different shapes, and smaller than the gaps but able to bridge them. Mixtures of sealing agents may be used. The sealing agent may be added with the ball sealers, after the ball sealers, or both. | 09-22-2011 |
| 20110232908 | ADDITIVE AND METHOD FOR SERVICING SUBTERRANEAN WELLS - Disclosed is a weighting agent comprising processed taconite, and methods of applying the weighting agents during the completion of subterranean wells. The processed taconite is ground such that the particle-size distribution is comparable to and compatible with other suspended solids in fluids such as, but not limited to, drilling fluids, lost-circulation-control fluids, spacer fluids, cement slurries and temporary pills. | 09-29-2011 |
| 20110232909 | METHODS AND APPARATUSES FOR MIXING DRILLING FLUIDS - A method of mixing drilling fluids, the method including injecting a drilling fluid into a high shear mixing unit and processing the drilling fluid with the high shear mixing unit. The processing includes forcing the drilling fluid through a first row of teeth of a first stage. | 09-29-2011 |
| 20110247821 | COMPOSITIONS AND METHOD FOR BREAKING HYDRAULIC FRACTURING FLUIDS - Breaking compositions are disclosed for controlled breaking of borate cross-linked fracturing fluids, and to method for making and using same, where the composition includes an oxidative component and an ester component. | 10-13-2011 |
| 20110247822 | METHOD OF CONTACTING HYDROCARBON-BEARING FORMATIONS WITH FLUORINATED ETHER COMPOSITIONS - Method comprising contacting a hydrocarbon-bearing formation with a composition comprising solvent and a fluoropolyether compound, wherein the fluoropolyether compound comprises at least one first divalent unit represented by formula: Each Rf is independently selected from the group consisting of Rf | 10-13-2011 |
| 20110247823 | METHOD OF CONTACTING HYDROCARBON-BEARING FORMATIONS WITH FLUORINATED PHOSPHATE AND PHOSPHONATE COMPOSITIONS - Method comprising contacting a hydrocarbon-bearing formation with a composition comprising solvent and a fluoropolyether compound. The fluoropolyether compound: is represented by formula Rf—[C(0)—NR | 10-13-2011 |
| 20110259592 | METHOD AND COMPOSITION FOR TREATING FLUIDS BEFORE INJECTION INTO SUBTERRANEAN ZONES - The invention relates to methods and compositions for producing or recovering an aqueous-based fluid to be utilized or injected in a wellbore or surrounding subterranean formation. The method comprises the step of contacting an aqueous-based fluid with an aqueous-soluble breaker composition comprising an oxidizing agent and a catalyst for a time sufficient to reduce or eliminate one or more deleterious substances in the aqueous-based fluid to produce a treated aqueous-based fluid suitable for use or injection in a wellbore or surrounding subterranean formation. | 10-27-2011 |
| 20110265997 | VISCOSIFICATION AND FOAMING OF POLYACRYLAMIDES - Embodiments of the invention relate to a method for treating a subterranean formation, comprising forming a fluid comprising polyacrylamide and a biopolymer and introducing the fluid to a subterranean formation wherein the polyacrylamide and biopolymer are selected to form the fluid with a longer foam half life and a higher viscosity than if only one polymer were selected. Embodiments of the invention relate to a method for treating a subterranean formation, comprising forming a fluid comprising polyacrylamide and a biopolymer and introducing the fluid to a subterranean formation wherein the polyacrylamide does not alter biopolymer crosslinking. | 11-03-2011 |
| 20110272158 | High pressure manifold trailer and methods and systems employing the same - A method of servicing a subterranean formation with a servicing fluid, the method comprising providing a first component of the servicing fluid to a first high-pressure pump at a first pressure, providing a second component of the servicing fluid to a second high-pressure pump at a second pressure, increasing the pressure of the first component of the servicing fluid at the first high-pressure pump to a third pressure, wherein the third pressure is greater than the first pressure, increasing the pressure of the second component of the servicing fluid at the second high-pressure pump to a fourth pressure, wherein the fourth pressure is greater than the second pressure, communicating the first component of the servicing fluid to a high-pressure manifold, communicating the second component of the servicing fluid to the high-pressure manifold, communicating the first component of the servicing fluid from a first high-pressure manifold outlet to a wellhead located at a wellbore, communicating the second component of the servicing fluid from a second high-pressure manifold outlet to the wellhead, and mixing the first component of the servicing fluid and the second component of the servicing fluid at the wellhead to form the servicing fluid. | 11-10-2011 |
| 20110284225 | Shear Tolerant Aqueous Based Fracturing Fluids and Methods - A method comprises providing a treatment fluid comprising a gelling agent, an aqueous base fluid, a buffer composition comprising a plurality of salts, and a crosslinking agent; and contacting a subterranean formation with the treatment fluid. The method may be used in subterranean formation having a temperature greater than about 200° F., and the treatment fluid useful with the method may have a high shear recovery greater than 100%. | 11-24-2011 |
| 20110284226 | System And Method For Controlling One Or More Fluid Properties Within A Well In A Geological Volume - A property of fluid within a well in a geological volume is controlled. The property of the fluid may include fluid density, pressure gradient, temperature, foaming characteristics, and/or other fluid properties within the well. In particular, the fluid property is controlled discretely within different sections (e.g., at different depths) of the well. This may enhance the structural stability of the well. | 11-24-2011 |
| 20110290491 | WELL SERVICING FLUID - A nano-dispersion well servicing fluid is disclosed. The well servicing fluid is formulated with components comprising: nanoparticles comprising at least one material chosen from aluminum oxides, aluminum hydroxides, aluminum hydroxyoxides, zirconium oxides, zirconium hydroxides, zirconium hydroxyoxides, wherein the concentration of nanoparticles is greater than 0.5% by weight based on the total weight of the nano-dispersion well servicing fluid. The well servicing fluid also comprises an aqueous base continuous phase. Methods of employing the nano-dispersion to service a wellbore are also disclosed. | 12-01-2011 |
| 20110290492 | BLENDING SYSTEM AND METHOD FOR PREPARING EMULSIONS - Embodiments of the current application are generally related to systems and methods for preparing emulsions. In some embodiments, there is disclosed an on-site emulsifying system comprising a first fluid tank, a second fluid tank, a circulation loop comprising a buffer tank and a pump. The first fluid tank and the second fluid tank are in fluid communication with the circulation loop via a first fluid inlet pipe and a second fluid inlet pipe, respectively. An outlet pipe is in fluid communication with the circulation loop. | 12-01-2011 |
| 20110303414 | Method for Improving the Clean-Up of Emulsified Acid Fluid Systems - Using a complex emulsion for treating a subterranean formation, such as to dissolve minerals therein (e.g. carbonates, scales, and/or filter cake) to improve permeability, substantially improves post treatment fluid clean-up for improved hydrocarbon production. The complex emulsion is made by mixing an acid aqueous phase with an oil external microemulsion to give an initial product, where the acid aqueous phase is an external phase and the microemulsion is an internal phase. Then the initial product is mixed with a second oil (e.g. xylene, diesel, toluene, kerosene, other aromatics, refined hydrocarbons and the like) containing an emulsifier to make a complex emulsion. | 12-15-2011 |
| 20110308802 | DEGRADABLE MATERIAL FOR DIFFERENT OILFIELD APPLICATIONS - This invention relates to compositions and methods A method of treating a subterranean formation including forming a fluid comprising zein, and introducing the fluid to a subterranean formation. A method of treating a subterranean formation comprising a wellbore, including introducing a tubular to the wellbore wherein the tubular comprises zein. | 12-22-2011 |
| 20110315384 | GELLED FOAM COMPOSITIONS AND METHODS - The invention provides a method made of steps of injecting into a wellbore, a composition comprising a solvent, a surfactant, a foaming gas, a foam enhancer, a crosslinkable polymer, and a crosslinking agent capable of crosslinking the polymer, wherein the foam enhancer increases the foam half-life of the gel composition compared to the gel composition without the foam enhancer; and allowing viscosity of the composition to increase and form a gel. | 12-29-2011 |
| 20110315385 | CALCIUM CARBONATE TO INCREASE VISCOSITY OF POLYACRYLAMIDE FLUIDS - Compositions and methods of treating a subterranean formation including forming a fluid comprising polyacrylamide and calcium carbonate and introducing the fluid to the formation, wherein the viscosity of the fluid is higher than if no calcium carbonate is present. Compositions and methods of treating a subterranean formation penetrated by a well bore including forming a fluid comprising polyacrylamide, calcium carbonate, and crosslinker, and introducing the fluid to the formation, wherein the fluid viscosity at 100 s-1 is increased from 300 cP to 600 cP at a temperature of 93 degC. Compositions and methods of treating a subterranean formation penetrated by a well bore including forming a fluid comprising polyacrylamide and barium carbonate and introducing the fluid to the formation, wherein the viscosity of the fluid is higher than if no barium carbonate is present. | 12-29-2011 |
| 20110315386 | PROCESS FOR SEQUESTRATION OF FLUIDS IN GEOLOGICAL FORMATIONS - A process for geo-sequestration of a water-soluble fluid includes selection of a target water-laden geological formation bounded by an upper formation of low permeability, providing an injection well into the formation and injecting the fluid into the injection well under conditions of temperature, pressure and density contrast selected to cause the fluid to enter the formation and rise within the formation. This generates a density-driven convection current of formation water which promotes enhanced mixing of the water-soluble fluid with formation water. | 12-29-2011 |
| 20120000658 | METHOD FOR IN SITU FLUID ASSESSMENT AND OPTIMIZATION DURING WELLBORE DISPLACEMENT OPERATIONS - The present invention is, in some embodiments directed to methods for optimizing wellbore displacement operations via in situ fluid property assessment/monitoring. By monitoring fluid properties in situ (i.e., downhole), fluid property assessment is direct instead of being inferred. Additionally, wherein such assessment/monitoring is carried out in real time, changes to the displacement fluid can be made “on-the-fly,” thereby contributing to an enhancement of the overall efficiency of the method. | 01-05-2012 |
| 20120000659 | Multifunctional Boronic Crosslinkers and Associated Methods - A method of treating a subterranean formation comprises providing a treatment fluid comprising: an aqueous fluid; a gelling agent, and a multifunctional boronic crosslinker comprising two or more boronic functional groups; and introducing the viscosified fluid into a subterranean formation. | 01-05-2012 |
| 20120006549 | WELL SERVICING FLUID - A well servicing fluid formulated with ingredients comprising a viscosifying polymer that is a crosslinked copolymer of an ethylenically unsaturated dicarboxylic anhydride and an alkyl vinyl ether, or the di-acid thereof; a pH adjuster capable of maintaining a pH of 5.5 or greater; and a solvent. Methods of treating a well formation with the wellbore servicing fluid and methods of making the wellbore servicing fluid are also disclosed. | 01-12-2012 |
| 20120006550 | Split Stream Oilfield Pumping Systems - A method of pumping an oilfield fluid from a well surface to a wellbore is provided that includes providing a clean stream; operating one or more clean pumps to pump the clean stream from the well surface to the wellbore; providing a dirty stream including a solid material disposed in a fluid carrier; and operating one or more dirty pumps to pump the dirty stream from the well surface to the wellbore, wherein the clean stream and the dirty stream together form said oilfield fluid. | 01-12-2012 |
| 20120012320 | POLYMERIZING AND ANCHORING A WATER-SOLUBLE POLYMER TO AN IN-PLACE MINERAL SURFACE OF A WELL - Methods are provided using an anchoring agent for a water-soluble polymer that is in-place polymerized in a subterranean formation. The anchoring agent comprises a hydrolyzable silyl group that reacts with one or more dangling hydroxyl groups of a mineral surface in the subterranean formation to form “hard” bonds, “anchoring” to the mineral surface. The anchoring agent is selected to have another functional group for covalent attachment to the water-soluble polymer. This can help a water-soluble polymer be anchored to a mineral surface in a subterranean formation. Accordingly, it is believed that monomolecular layers of water-soluble polymer will be formed and anchored to the mineral surface, which will provide excellent elastic properties to the matrix. The monomolecular layers are not expected to interfere with the permeability of the matrix. | 01-19-2012 |
| 20120012321 | Method for Producing Natural Gas from Hydrocarbon Hydrates While Simultaneously Storing Carbon Dioxide in Geological Formations - The invention relates to a method for extracting methane from methane hydrates, comprising the following steps: feeding carbon dioxide to the methane hydrate deposits; allowing the carbon dioxide to take effect on the methane hydrate to release methane and store the carbon dioxide as carbon dioxide hydrate; and removing the released methane, characterised in that the fed carbon dioxide is supercritical carbon dioxide. | 01-19-2012 |
| 20120018159 | Polymer Hydration Method - Disclosed is a method of rapidly hydrating a hydratable polymer, which method involves irradiating with radio frequency electromagnetic radiation, a mixture of at least the polymer and an aqueous hydrotreating medium to form a viscosified mixture of at least aqueous hydrotreating medium and hydrated polymer. Related methods of treating a subterranean formation and continuously hydrotreating a subterranean formation are also revealed. | 01-26-2012 |
| 20120018160 | New Oil Recovery Process for Carbonate Reservoirs - A method for increasing oil production in a carbonate reservoir by conducting a step-wise reduction of salinity of the injected salt water that is injected into the carbonate reservoir. The method provides for increased oil production as compared to conventional waterflooding techniques. | 01-26-2012 |
| 20120018161 | Oil Recovery Process for Carbonate Reservoirs - A method for increasing oil production in a carbonate reservoir by incorporating a diluted surfactant injection in conjunction with conducting a step-wise reduction of salinity of the injected salt water that is injected into the carbonate reservoir. The method provides for increased oil production as compared to conventional waterflooding techniques. | 01-26-2012 |
| 20120024529 | Stimuli-Responsive High Viscosity Pill - A method comprises providing a treatment fluid having a first viscosity comprising an aqueous base fluid; a viscoelastic surfactant; and a stimuli-responsive water-soluble polymer; introducing the treatment fluid into a subterranean formation; and allowing the treatment fluid viscosity to change to a second viscosity in response to a stimulus. | 02-02-2012 |
| 20120031617 | FORMATION TREATMENT SYSTEM AND METHOD - A formation treatment system includes an annulus spanning member having one or more openings therein. A tubular having one or more ports therein in fluid communication with the one or more openings. A sleeve capable of isolating or communicating the one or more ports with an ID of the tubular. A method for effecting precision formation treatment is included. | 02-09-2012 |
| 20120031618 | Use of Hexose Oxidases to Create Hydrogen Peroxide in Aqueous Well Treatment Fluids - A hydrocarbon-bearing subterranean formation may be treated with an aqueous well treatment fluid which contains a hexose oxidase, such as glucose oxidase, mannose oxidase or galactose oxidase. The aqueous well treatment fluid further may contain a viscosifying polymer and an aldohexose. The aldohexose reacts in-situ with the hexose oxidase and molecular oxygen to produce hydrogen peroxide. The hydrogen peroxide may then act as a breaker. | 02-09-2012 |
| 20120037371 | Well Servicing Fluid - The present disclosure is directed to a method of servicing a well. The method comprises providing a well servicing fluid. The well servicing fluid is formulated with the following components comprising, at least one friction reducer chosen from polychloroprenes, vinyl acetate polymers, polyalkylene oxides polyalphaolefins; and a nonaqueous carrier fluid. The well servicing fluid is introduced into the well. | 02-16-2012 |
| 20120037372 | Recovery or Storage Process - A method for recovering gases and/or liquids stored within one or more gas and/or liquid reservoirs comprising locating the upper consolidated boundary of the one or more gas and/or liquid reservoirs; drilling an access well which extends downwardly to at least adjacent the upper consolidated boundary of the one or more gas and/or liquid reservoirs; drilling a section of the access well extending along or adjacent at least a portion of the upper consolidated boundary of the one or more gas and/or liquid reservoirs; creating permeability pathways into the one or more gas and/or liquid reservoirs to enable the release of gas and/or liquid from the one or more gas and/or liquid reservoirs into the access well; and recovering the released gas and/or liquid through the access well. The method is also used for storage or sequestering of gases and/or liquids into one or more gas and/or liquid reservoirs wherein permeability pathways are created to inject the gases and/or liquids into the reservoirs from the access well. | 02-16-2012 |
| 20120043084 | SYSTEM AND METHOD FOR ENHANCING COAL BED METHANE RECOVERY - A system includes first and second wells. The first well has a first tube that extends from a first well head to a first end disposed within a coal seam. The second well is disposed at a distance from the first well and includes a second tube that extends from a second well head to a second end disposed within the coal seam. A pump is coupled to the first well and is configured to supply the first tube with pressurized fluid that includes nutrients for methanogenesis. At least a portion of the pressurized fluid introduced into the first tube of the first well is received within the second tube of the second well by way of the coal seam. | 02-23-2012 |
| 20120055673 | Method for dispersing aqueous based drilling fluid for drilling subterranean boreholes - An inhibitive water-based polymer mud system and method for using the system in drilling and in stabilizing wellbores is disclosed for use in water sensitive formations as an alternative to oil-based muds or water-based muds comprising ferro-chrome lignosulfonates. The system comprises a fresh water or salt water base thinned or dispersed with a sulfonated acrylic copolymer having a hybrid/graft lignosulfonate multipolymer structure containing carboxylate and sulfonate functional groups with synthetic polymer side chains covalently linked to a base lignosulfonate material, having a molecular weight in the range of about 1,000 to about 15,000, and having a high anionic charge density. This system is effective and has stable rheology over a broad pH range, even at a near neutral pH of 8.0. The drilling fluids do not contain heavy metals and are rheologically tolerant to contaminants such as cement, anhydrite and sodium and temperatures as high as about 400° F. | 03-08-2012 |
| 20120055674 | DETECTING AND CORRECTING UNINTENDED FLUID FLOW BETWEEN SUBTERRANEAN ZONES - Detecting and correcting unintended fluid flow between subterranean zones. At least some of the illustrative embodiments are methods that include: injecting a first fluid into a subterranean zone, the injecting by way of a first borehole; making a reading indicative of surface deformation; identifying, based on the surface deformation reading, a flow path for a second fluid out of the subterranean zone; drilling a second borehole that intersects the flow path; and placing a sealing compound into the flow path by way of the second borehole, the sealing compound reduces the flow of the second fluid through the flow path. | 03-08-2012 |
| 20120061082 | SEALING OF THIEF ZONES - The present invention provides a method for selectively sealing a thief zone in a hydrocarbon reservoir located in a calcium-rich formation and penetrated by a borehole comprising injecting into the thief zone a sealing fluid comprising a mixture of and hydronium ions (H | 03-15-2012 |
| 20120061083 | WELLBORE FLUID AND METHODS OF TREATING AN EARTHEN FORMATION - 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. | 03-15-2012 |
| 20120061084 | Detecting and Correcting Unintended Fluid Flow Between Subterranean Zones - Detecting and correcting unintended fluid flow between subterranean zones. At least some of the illustrative embodiments are methods including: injecting a first fluid into a subterranean zone, the injecting by way of a first borehole; making a reading indicative of surface deformation; identifying, based on the reading indicative of surface deformation, a flow path for a second fluid out of the subterranean zone; placing a compound into the flow path, the compound reduces the flow of the second fluid through the flow path. | 03-15-2012 |
| 20120073817 | Tethered Polymers Used to Enhance the Stability of Microemulsion Fluids - Of the methods provided in this invention, one method includes: providing a treatment fluid comprising: an aqueous fluid, a microemulsion surfactant, and an amphiphilic polymer, wherein the amphiphilic polymer comprises a hydrophobic component, and a hydrophilic component; and introducing the treatment fluid into a subterranean formation, wherein the microemulsion surfactant forms a microemulsion that comprises the amphiphilic polymer within the subterranean formation. | 03-29-2012 |
| 20120073818 | Mixing Tank and Method of Use - A method of transmitting a fluid into an oil well bore provides a frame supporting a vessel, the vessel having an interior, upper and lower end portions, a conically shaped side wall, and an outlet for discharging the fluid from the vessel. A viscous polymeric material is added to the vessel interior. A discharge pipe having a vertical section is placed below the vessel, the discharge pipe being in communication with the outlet. A positive displacement pump is contained within the discharge pipe. The pump transmits fluid from the outlet into the discharge pipe downstream of the vertical pipe section or pump. The fluid is selectively transmitted to either the vessel interior (for recirculating) or into the well. Air is added to the discharge flow line downstream of the pump. | 03-29-2012 |
| 20120085540 | METHOD AND AN APPARATUS FOR DOWNHOLE INJECTING ONE OR MORE TREATMENT FLUIDS - Method and apparatus for downhole injecting one or more treatment fluids, and especially for providing one or more seals in an annular space between a well tubular and the surrounding formation or between pipes of a wellbore system, said method comprising the steps of loading the or each treatment fluid separately into one or more fluid containers ( | 04-12-2012 |
| 20120090846 | MODIFICATION OF SOLID POLYSACCHARIDE WITH TRANSESTERIFICATION AGENT - Polysaccharides, for example xanthan, diutan, scleroglucan, gums, celluloses, and starches, and derivatives of the foregoing, are reacted with organic carbonates forming products that: (1) have increased viscosifying efficiency, i.e., higher viscosities at reduced concentrations compared to the unmodified polysaccharide; or (2) are insolubilized at temperature ranges for which the unmodified polysaccharide would hydrate fully; or (3) both properties. In some cases, the insolubilized polysaccharides can be activated to dissolve and viscosify at specific temperature ranges by using pH modifiers. A method of treating a well is provided, including the steps of: (a) obtaining a modified polysaccharide characterized by having been made by the process of combining: (i) a water-soluble polysaccharide, wherein the polysaccharide is in a solid form during the combining step; and (ii) a transesterification agent, wherein the transesterification agent is in liquid form; wherein the step of combining is in the presence of less than 10% by weight water relative to the water-soluble polysaccharide and wherein any water present is at a pH of 8 or less; (b) forming a treatment fluid comprising the modified polysaccharide and water; and (c) introducing the treatment fluid into the well. | 04-19-2012 |
| 20120090847 | Tools and Methods for Use in Completion of a Wellbore - 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. | 04-19-2012 |
| 20120103613 | COAL FINES FLOCCULATION FROM PRODUCED WATER USING OIL-SOLUBLE PHOSPHATE ESTER - A method of flocculating coal fines from produced water is provided. The method includes the steps of: (A) mixing at least: (i) produced water, wherein the produced water comprises suspended coal fines; (ii) one or more oil-soluble phosphate esters; and (iii) water-immiscible solvent; wherein the mixing is in proportions to obtain an oil-in-water emulsion; (B) allowing or mechanically causing the oil-in-water emulsion to substantially break into: (i) a first fluid having a continuous phase comprising at least some of the water from the produced water; and (ii) a second fluid having a continuous phase comprising at least some of the water-immiscible solvent; and (C) mechanically separating the first fluid and the second fluid. Optionally, the step of mixing further includes mixing with a crosslinker for the one or more phosphate esters to form a gel for suspending the separated coal fines. | 05-03-2012 |
| 20120103614 | Method of Treating a Borehole and Drilling Fluid - A method of treating a borehole is provided, wherein the method comprises introducing a drilling fluid into a borehole, wherein the drilling fluid comprises an ionic liquid. In particular, the ionic liquid may comprise a single ionic liquid, i.e., only one kind of anion and one kind of cation, or may comprise a mixture of different ionic liquids, e.g., may comprise several different anions and/or several different cations. | 05-03-2012 |
| 20120111567 | FORMATE SALTS FOR INCREASED STABILITY OF POLYACRYLAMIDE FLUIDS - Methods and apparatus for using a fluid within a subterranean formation, including forming a fluid comprising an acrylamide copolymer and a formate salt, and introducing the fluid to the subterranean formation, wherein a temperature of the formation is about 149° C. or warmer. Also, methods and apparatus for a fluid for use within a subterranean formation, including an acrylamide copolymer comprising polyacrylamide, a formate salt comprising potassium, and a crosslinker comprising zirconium. Additionally, methods and apparatus for using a fluid within in a subterranean formation, including forming a fluid comprising an acrylamide copolymer and a formate salt, and introducing proppant into the fluid to form a mixture, introducing the mixture to the subterranean formation, wherein a temperature of the formation is about 149° C. or warmer. | 05-10-2012 |
| 20120125615 | MIXING TANK AND METHOD OF USE - A method of transmitting a fluid into an oil well bore provides a frame supporting a vessel, the vessel having an interior, upper and lower end portions, a conically shaped side wall, and an outlet for discharging the fluid from the vessel. A viscous polymeric material is added to the vessel interior. A discharge pipe having a vertical section is placed below the vessel, the discharge pipe being in communication with the outlet. A positive displacement pump is contained within the discharge pipe. The pump transmits fluid from the outlet into the discharge pipe downstream of the vertical pipe section or pump. The fluid is selectively transmitted to either the vessel interior (for recirculating) or into the well. Air is added to the discharge flow line downstream of the pump. In one embodiment, the vessel contains a flexible bladder or bag that holds the material to be pumped. | 05-24-2012 |
| 20120125616 | METHOD FOR INTEGRATED ENHANCED OIL RECOVERY FROM HETEROGENEOUS RESERVOIRS - The invention relates to a method of recovering oil from a heterogeneous reservoir, comprising a plurality of permeable porous blocks of rock whose pores contain oil and which form interfaces with regions between the blocks, e.g. fractures, having a higher permeability than the blocks. The method comprises the steps of treating the interfaces such that the wettability of the surfaces of the blocks is in a predetermined wettability range, then reducing the permeability in the highly permeable regions, and finally flooding the reservoir by injecting a chase fluid into the reservoir. With the inventive method water phase bridges are established between adjacent blocks in the reservoir thus allowing a transmission of injection pressure for viscous displacement from one block to the next across the reservoir. The invention also relates to a method for long-time storage of CO | 05-24-2012 |
| 20120145400 | METHOD FOR MIXING FLUIDS DOWNHOLE - Methods and devices for mixing a first fluid with a second fluid downhole include a chamber having a first end, a second end and an opening for fluid to flow there through. A top surface of a piston is capable of contacting the second end of the chamber. The piston is located at a first position within the chamber based upon characteristics of a second fluid. A fluid delivery system supplies the first fluid and supplies a second fluid through a first opening of the chamber, wherein the second fluid is at a pressure that moves the piston approximate to the second end of the chamber. The piston includes an agitator mixing device that is attached to a bottom surface of the piston, wherein mixing of the first fluid with the second fluid primarily occurs upon movement of the piston by actuating device. | 06-14-2012 |
| 20120145401 | Acidic Treatment Fluids Containing Non-Polymeric Silica Scale Control Additives and Methods Related Thereto - The present invention relates to treatment fluids and compounds useful in subterranean formations, particularly those that retard deposition of silica scale in subterranean formations. Methods of the present invention 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. | 06-14-2012 |
| 20120152546 | CHEMICAL OXIDATION OR ELECTROMAGNETIC TREATMENT IN SAGD OPERATIONS - A system for treating produced water, for example from a SAGD bitumen production operation, has a treatment unit using chemical oxidation (CO) or electromagnetic treatment (ET) to destroy or degrade organics in the produced water. The treatment module may use CO or ET in combination with biological treatment or sorption processes or both. When the treatment module is used upstream of a steam generator, it reduces fouling in the steam generator and in any blowdown water treatment device. A brine concentrator or a crystallizer may be used to treat the blowdown water. The treatment module may be used in combination with a nanofiltration (NF) or reverse osmosis (RO) membrane filter. Optionally, the produced water may be treated with an ET process such as microwaves directly upstream of a steam generator or upstream of a concentrator or crystallizer in a blowdown water stream. | 06-21-2012 |
| 20120152547 | WETTABILITY ANALYSIS OF DISAGGREGATED MATERIAL - A method for determining wettability of a solid, such as a reservoir rock material, is described. The method includes disaggregating the material, for example by grinding and placing the disaggregated material on the surface of the fluid. The wettability is analyzed based on whether a portion of the material floats on or sinks into the fluid. The method is well suited for heterogeneous solid materials that have mixed wetting characteristics and/or have varying surface types. The fluid can be evaluated as a potential treatment fluid or a component thereof that can be used for treating the rock formation. For example, the potential treatment fluid can include a surfactant or an oxidizing agent. A simple observation can be made whether substantially all of the material placed on the surface of the fluid sinks into the fluid, or the portions of floating and sinking material can be weighed. | 06-21-2012 |
| 20120152548 | METHOD TO CHARACTERIZE UNDERGROUND FORMATION - A method for determining a characteristic of an underground formation with a fluid is described. The method includes providing a sample material of the underground formation; measuring the permeability and the porosity of the sample material; performing a drainage test on the sample material using the fluid; estimating the threshold pressure of the sample material from the drainage test, the permeability and the porosity measurements; and determining the receding contact angle of the fluid on the sample material from the threshold pressure. The sample material can be disaggregated material. | 06-21-2012 |
| 20120160496 | METHOD FOR CONTROLLING THE DOWNHOLE TEMPERATURE DURING FLUID INJECTION INTO OILFIELD WELLS - Methods and apparatus for using a fluid within a subterranean formation comprising forming a fluid comprising a fluid additive, introducing the fluid to a formation, observing a temperature, and controlling a rate of fluid introduction using the observed temperature, wherein the observed temperature is lower than if no observing and controlling occurred. A method and apparatus to deliver fluid to a subterranean formation comprising a pump configured to deliver fluid to a wellbore, a flow path configured to receive fluid from the pump, a bottom hole assembly comprising a fluid outlet and a temperature sensor and configured to receive fluid from the flow path, and a controller configured to accept information from the temperature sensor and to send a signal. | 06-28-2012 |
| 20120160497 | Hydrocarbon Recovery Operations Fluids and Methods For Using the Same - Fluids for use in hydrocarbon recovery operations include water and at least one organo-anionic surfactant. The fluids may be used in methods for conducting hydrocarbon recovery operations, such as drilling operations, completion operations, production operations, injection operations. The fluid may be adapted to remediate a NAF filter cake. Exemplary organo-anionic surfactants may include one or more of monoethanol ammonium alkyl aromatic sulfonic acid, monoethanol ammonium alkyl carboxylic acid, and mixtures thereof. | 06-28-2012 |
| 20120168164 | METHOD AND APPARATUS FOR CONTROLLING FLUID FLOW INTO A WELLBORE - In one aspect, an injection apparatus for use in a wellbore is disclosed wherein the apparatus includes a tubular housing and a shield housing disposed outside the tubular housing, the shield housing including a chamber in fluid communication with the tubular housing. The apparatus further includes a piston disposed within the shield housing, the piston coupled to a biasing member, wherein movement of the piston controls fluid communication between the chamber and the wellbore, and wherein the movement of the piston is caused by a pressure change of a fluid within the tubular housing. | 07-05-2012 |
| 20120168165 | METHOD FOR INTERVENTION OPERATIONS IN SUBSURFACE HYDROCARBON FORMATIONS - Nanoparticles are added to a fluid containing a wetting agent to enhance wetting of solid surfaces in and around the well and removing a water-block from the well. The wetting agent and nanoparticles combine to produce a wetting of the surfaces of the rock that allows recovery of the excess water near the well (water block). | 07-05-2012 |
| 20120181028 | Method and system for servicing a wellbore - A method of servicing a wellbore, comprising transporting a plurality of wellbore servicing equipment to a well site associated with the wellbore, accessing a water source to form a water stream from the water source to at least one of the plurality of wellbore servicing equipment, passing a direct electrical current through the water stream obtained from the water source to coalesce an undissolved solid phase and an undissolved organic phase in the water stream, separating the coalesced undissolved solid phase and the coalesced undissolved organic phase from the water stream to yield a substantially single-phase water stream, adding ozone to the substantially single-phase water stream to yield an ozonated water stream, irradiating the ozonated water stream with ultraviolet light to yield an irradiated water stream, forming a wellbore servicing fluid using the irradiated water stream, and placing the wellbore servicing fluid into the wellbore. | 07-19-2012 |
| 20120199353 | WELLBORE INJECTION SYSTEM - A device is provided for delivering and distributing injection fluids into a subsurface formation from a horizontal wellbore. The device includes one or more steam pups having an outer sleeve and an inner sliding sleeve in concentric relationship. One or more sets of nozzles are arranged on the outer sleeve. A means is provided for actuating movement of the inner sliding sleeve within the outer sleeve, to at least partially cover one or more sets of nozzles on the outer sleeve. A method is also provided for delivering injection fluids into a subsurface formation from a horizontal wellbore. First, one or more steam pups are introduced into the horizontal well, said steam pups having an outer sleeve and an inner sliding sleeve with one or more sets of nozzles arranged on the outer sleeve. Next the inner sliding sleeve is moved inside the outer sleeve to at least partially cover one or more sets of nozzles on the outer sleeve. Finally, injection fluid is injected through the steam pup nozzles into formation. A further method is provided that comprises introducing into a heel location of the wellbore a first and second pairs of flow control hangers and polished bore receptacles, connected to an intermediate casing and cemented in place. The first pair of flow control hanger and polished bore receptacle are connected to an injection/production liner and one or more steam pups are then connected to the second pair of flow control hanger and polished bore receptacle. | 08-09-2012 |
| 20120199354 | System and Method For Producing Geothermal Energy - Methods and systems are provided for extracting geαthermal heat from neighboring or proximate/ones in a fractured rock formation. The extraction of heat may be performed by cycling between injection and production using separate wells for each zone and offsetting the injection-production cycles between neighboring zones, for example, by keeping the injection-production cycle;* for neighboring zones out of phase with each other. The techniques provide for improved heal recover}’ from rock volumes while decreasing the size of buffer/ones between neighboring/ones, her example, in exemplary embodiments of the present techniques, proximate zones may be within 1000 meters, or even less, of each other. Accordingly, the zones do not have to be totally isolated from each other. The methods and systems described herein may help to impede cross-flow between the zones while minimizing waste heat (and well separation) from unutilized rock layers left between wells. | 08-09-2012 |
| 20120199355 | WATER FLOODING METHOD FOR SECONDARY HYDROCARBON RECOVERY - A water flooding composition in a method of secondary hydrocarbon recovery. The water flooding composition includes water and a thickening polymer. The thickening polymer includes a hydroxyethyl cellulose backbone polymer having a molecular weight of between about 1,000,000 and about 2,000,000 and a hydrophobic modifier. The hydrophobic modifier has a substitution level in the thickening polymer of between about 0.1 percent and about 2 percent by weight of the thickening polymer. The hydrophobic modifier is an alkyl hydrocarbon based material containing between about 10 and about 24 unsubstituted carbon atoms per group. The thickening polymer has a concentration in the water flooding composition of between about 0.01 percent and about 1 percent by weight of the water flooding composition. The water flooding composition is formulated within these ranges so that the water flooding composition has a suitable viscosity/mobility and so that the water flooding composition is injectable. | 08-09-2012 |
| 20120205110 | Wellbore Servicing Compositions and Methods of Making and Using Same - A method of servicing hydrocarbon production equipment comprising locating at least a portion of a hydrocarbon flow conduit experiencing a loss of functionality; creating a port to access an interior flow bore of the hydrocarbon flow conduit; installing at least one piece of equipment proximate the access port, wherein the equipment has access to the interior flow bore via the access port; and placing a servicing composition into the conduit via the access port, wherein the servicing composition prevents the loss of materials from the interior of the hydrocarbon flow conduit to the surrounding environment. | 08-16-2012 |
| 20120211228 | Artificial Lift Modeling Methods and Systems - Methods for modeling, configuring, and controlling artificial lift processes are provided as well as systems for controlling artificial lift and hydrocarbon production systems. In particular, the methods and systems include the use of computation solid-liquid slurry models and reservoir inputs configured to provide inputs to configure parameters of an artificial lift system. The methods and systems may also incorporate fluid lift computational models and volume of fluid (VOF) models for verifying the numerical results. The disclosed methods and systems may beneficially be used in combination with hydrocarbon production processes such as fluidized in-situ reservoir extraction (FIRE) process; a SRBR process; an enhanced CHOPS process; and any combination thereof. | 08-23-2012 |
| 20120217011 | Apparatus and method for high pressure abrasive fluid injection - A system for injecting high pressure abrasive fluid into an abrasive jet tool in a wellbore comprises an abrasives hopper; a slurry tank connected to the abrasives hopper; a low pressure abrasive pump connected to the slurry tank; a first high pressure vessel connected to the low pressure pump through a first high pressure valve; a high pressure non-abrasive pump connected to the first high pressure vessel through a second high pressure valve; and an abrasive jet tool connected to the first high pressure vessel through a third high pressure valve. | 08-30-2012 |
| 20120217012 | METHOD OF INTRODUCING TREATMENT AGENTS INTO A WELL OR FLOW CONDUIT - A treatment agent retained in a housing may be slowly and continuously released into a targeted area in a well or in a flow conduit. The housing contains a confinement area. Movement of the treatment agent is limited in the confinement area by a retainer. | 08-30-2012 |
| 20120241156 | SELECTIVE FLUID WITH ANCHORING AGENT FOR WATER CONTROL - Methods and apparatus for using a fluid within a subterranean formation including forming a fluid comprising an oil-soluble resin acid and an organosilicon compound and introducing the fluid to the formation, wherein the relative permeability of the formation increases, and wherein the production of water is reduced more than if no fluid was introduced to the formation. Methods and apparatus for reducing water production within a subterranean formation including forming a fluid comprising an oil-soluble resin acid and an organosilicon compound and introducing the fluid to the formation, wherein the production of water is reduced more than if no fluid was introduced to the formation. | 09-27-2012 |
| 20120247774 | SLOW RELEASE BREAKER TREATMENT FLUIDS AND THEIR ASSOCIATED METHODS OF USE - A method of treating a portion of a subterranean formation comprises providing a treatment fluid comprising a carrier fluid, a viscosifying agent, a breaker, and a breaker aid wherein the breaker aid slowly releases a catalyst, wherein the viscosifying agent and the breaker in the carrier fluid have an initial viscosity and the catalyst and the breaker cooperate to decrease the viscosity of the treatment fluid below half of the initial viscosity after at least 30 minutes; and treating the subterranean formation. | 10-04-2012 |
| 20120255734 | MOBILE, MODULAR, ELECTRICALLY POWERED SYSTEM FOR USE IN FRACTURING UNDERGROUND FORMATIONS - The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems. | 10-11-2012 |
| 20120267111 | Synthesis of Degradable Polymers Downhole for Oilfield Applications - A method is given for polymerizing monomers downhole to create well treatment polymers. The monomers each contain two polymerizable groups and a degradable group or groups which allow the polymer to degrade under downhole conditions, for example by hydrolysis. Polymerization downhole allows easier, more precise, placement of polymer. Polymer obtained from monomers pumped downhole may be used, for example, for fluid diversion plugs, isolation plugs, formation consolidation, flowback control, and fluid loss control. Synthesized polymer may form gels, films, solids or other structure in treated wellbores, fractures, and/or formations. After the desired effect is achieved, the deposited polymer degrades and the polymer degradation products dissolve, leaving the wellbore, fracture and/or formation clean, with no damage that might have decreased fluid flow. | 10-25-2012 |
| 20120273202 | Controlled Production and Injection - A well production and injection string includes a plurality of spaced apart packers each adapted to seal with a wall of the wellbore. A plurality of flow control devices are provided in the string, distributed between pairs of adjacent packers. The flow control devices are adapted to communicate flow between an interior and an exterior of the string with less restriction to flow from the interior to the exterior of the string than to flow from the exterior to the interior of the string. | 11-01-2012 |
| 20120273203 | DOWNHOLE MIXING DEVICE FOR MIXING A FIRST FLUID WITH A SECOND FLUID - Methods and devices for mixing a first fluid with a second fluid downhole include a chamber having a first end, a second end and an opening for fluid to flow there through. A top surface of a perforated piston is capable of contacting the second end and a top surface of a piston is capable of contacting a bottom surface of the perforated piston. The perforated piston is located at a first position within the chamber based upon characteristics of a first fluid. A first fluid delivery system supplies the first fluid and a second fluid delivery system supplies a second fluid to the chamber, wherein the second fluid is at a pressure that moves the piston approximate to the first end. An actuating device applies a force against the bottom surface of the piston to inject the fluids through channels of the perforated piston to produce spray droplets. | 11-01-2012 |
| 20120273204 | ZERO EMISSION LIQUID FUEL PRODUCTION BY OXYGEN INJECTION - An enhanced oil recovery method is provided. This method includes; introducing a first essentially pure oxygen stream into a subterranean hydrocarbon-bearing formation traversed by at least one injection well and at least one production well, and initiating and sustaining in-situ combustion in the vicinity of the injection well. This method also includes introducing a second essentially pure oxygen stream and a hydrocarbon-containing fuel gas stream into the combustion device of a power generation system, wherein the combustion device produces an exhaust gas stream comprising water and carbon dioxide. This method also includes separating the exhaust gas stream into a stream of essentially pure water, and a stream of essentially pure carbon dioxide, and introducing at least a portion of the essentially pure carbon dioxide stream into the subterranean hydrocarbon-bearing formation prior to initiating the in-situ combustion. | 11-01-2012 |
| 20120285688 | METHOD OF WELL TREATMENT USING SYNTHETIC POLYMERS - A method for treating a subterranean formation, including estimating the solubility parameter of a monomer; selecting a solvent based on the parameter; forming a fluid comprising the monomer and solvent; and introducing the fluid to the formation, wherein the formation is about 350° F. or warmer. A method for treating a subterranean formation, including forming a fluid comprising the monomer and solvent, wherein the monomer comprises poly(2-hydroxyethyl methacrylate) and/or poly(2-hydroxyethyl acrylate, and wherein the solvent comprises zinc bromide or calcium bromide or both; and introducing the fluid to the formation, wherein the formation is about 350° F. or warmer. | 11-15-2012 |
| 20120285689 | Methods and Compositions for Clay Control - Stabilizing a subterranean formation containing water-sensitive clays with methods including introducing a leading-edge fluid comprising a first base fluid and a first clay stabilizer solution wherein the first clay stabilizer is present in the first base fluid at a first concentration; and then introducing a treatment fluid comprising a second base fluid and a second clay stabilizer solution wherein the second clay stabilizer is present in the second base fluid at a second concentration, wherein the first concentration of clay stabilizer solution is higher than the second concentration of clay stabilizer solution. | 11-15-2012 |
| 20120285690 | Multi-Stage Methods and Compositions for Desensitizing Subterranean Formations Faces - A method of desensitizing a subterranean formation may include introducing a leading-edge fluid comprising a first base fluid and a first desensitizing agent into at least a portion of the subterranean formation, wherein the first desensitizing agent is present in the first base fluid at a first concentration; and then introducing a treatment fluid comprising a second base fluid and a second desensitizing agent into at least a portion of the subterranean formation, wherein the second desensitizing agent is present in the second base fluid at a second concentration, and wherein the first concentration is higher than the second concentration. | 11-15-2012 |
| 20120285691 | Permeability modification and water shut off composition and process - A composition and process for reducing the permeability of a matrix without completely blocking the matrix {is describe}. The composition uses a nano-sized water insoluble particle as a template to control the permeability by determining the size of the holes formed in the matrix. | 11-15-2012 |
| 20120292029 | LINEAR PRESSURE REDUCER FOR REGULATING INJECTION PRESSURE IN AN ENHANCED OIL RECOVERY SYSTEM - Linear pressure reducer apparatus for regulating injection pressure of a water-soluble polymer solution in injection wellheads, in an enhanced oil recovery system, including modules connected in series to the main injection pipe and each consisting of tubes of identical diameter but variable length, the apparatus allows variations to be made to pressure drop by adjusting the length of the tube through which the solution flows by closing or opening modules, without substantial degradation to the viscosity of the solution during its passage through the module. Installation for enhanced oil recovery implementing the apparatus. | 11-22-2012 |
| 20120298368 | Silica Control Agents for Use in Subterranean Treatment Fluids - Methods involving the use of subterranean treatment fluids comprising a silica control agent and an aqueous base fluid wherein the treatment fluid is placed into a portion of a subterranean formation and wherein the silica control agent is present in an amount of at least 75% of the saturation point in the treatment fluid. The methods include fracturing and gravel packing operations using a treatment fluid including a silica control agent present in an amount of at least 75% of the saturation point in the treatment fluid. | 11-29-2012 |
| 20120305254 | METHODS TO IMPROVE STABILITY OF HIGH SOLID CONTENT FLUID - A method of treating a subterranean formation of a well bore comprises providing a treatment fluid comprising a carrier fluid, a particulate material, a surfactant and micelles, wherein micelles are stabilized by the surfactant and act as particles in the treatment fluid; and introducing the treatment fluid into the wellbore. | 12-06-2012 |
| 20120318514 | METHODS OF TREATING A SUBTERRANEAN FORMATION CONTAINING HYDROCARBONS - A method of treating a subterranean formation containing hydrocarbons is disclosed, the method comprising: modifying the subterranean formation with a surface energy reducing agent; and injecting into the subterranean formation a fracturing fluid containing a base fluid and a gelling agent; in which the surface energy reducing agent is selected to effectively reduce the surface energy of the subterranean formation to at or below the surface tension of the gelling agent. | 12-20-2012 |
| 20120325482 | ALKALINE PERSULFATE FOR LOW-TEMPERATURE BREAKING OF MULTI-CHAIN POLYMER VISCOSIFIED FLUID - A persulfate compound activated by a strong base is used for low-temperature breaking of fluids viscosified with a multi-chain polysaccharide. The breaker system can be used in an oilfield or pipeline application where a multi-chain polysaccharide may be used in a fluid. It is particularly useful at low temperatures of less than 100° F. Optionally, the water can be a brine. | 12-27-2012 |
| 20120325483 | COMBINED MISCIBLE OR NEAR MISCIBLE GAS AND ASP FLOODING FOR ENHANCED OIL RECOVERY - A method for enhancing oil recovery by combining miscible or near miscible gas flooding with Alkaline-Surfactant-Polymer (ASP) flooding to produce an enhanced Water-Alternating-Gas (WAG) flooding method is described. The ASP flooding may include individual and combination injections of alkaline, surfactant and polymer. Carbon dioxide may be used as a flood gas. Numerical simulations show that the present method may provide better oil recovery when compared with separate ASP or CO | 12-27-2012 |
| 20130000911 | Gellable Treatment Fluids Comprising Quaternary Ammonium Salt Gel-Time Modifiers and Methods for Use Thereof - Methods for reducing the amount of water produced from a subterranean formation can include the use of a gellable treatment fluid that comprises a quaternary ammonium salt as a gel-time modifier. The gellable treatment fluids can comprise an aqueous base fluid, a base polymer comprising an acrylamide monomer unit, an organic crosslinking agent, and a gel-time modifier comprising a quaternary ammonium salt. | 01-03-2013 |
| 20130000912 | ALTERING THE INTERFACE OF HYDROCARBON-COATED SURFACES - Methods and compositions are provided wherein microorganisms are used to alter the interface of hydrocarbons and hydrocarbon-coated surfaces to increase oil recovery, for improved bioremediation and/or to benefit pipeline maintenance. | 01-03-2013 |
| 20130014950 | Methods of Well Cleanout, Stimulation and Remediation and Thermal Convertor Assembly for Accomplishing SameAANM DICKINSON; Theodore ElliotAACI HuffmanAAST TXAACO USAAGP DICKINSON; Theodore Elliot Huffman TX US - A thermal convertor is formed from a controlled combustion chamber selectively supplied by an appropriate fuel, preferably diesel, and compressed air. The control over the temperature of the combustion chamber is provided by regulating the flow of fuel, air and pressure into and out of the combustion chamber. Flow control valves open or close the inputs of fuel and water to, and the output of the superheated vapors from, the combustion chamber to specifically control the behavior of the combustion chamber and the composition and quality of the output from the combustion chamber. This assembly is then used to inject superheated nearly oxygen-free vapors including well treatment chemicals into a well bore cleaning the well, including the annulus and rathole, near-well bore and perforations of fines and asphaltenic particles, then stimulating an existing but newly cleaned well to produce additional oil. These methods can also be used to stimulate high paraffinic wells or wells with high viscosity crude oil, and for the maintenance of well pressure to enhance production rates. | 01-17-2013 |
| 20130014951 | APPLYING TREATMENT FLUID TO A SUBTERRANEAN ROCK MATRIXAANM Fitzpatrick; Harvey J.AACI KatyAAST TXAACO USAAGP Fitzpatrick; Harvey J. Katy TX US - The present disclosure relates to applying treatment fluid to a rock matrix in a subterranean formation. An injection fluid is received in a wellbore in a subterranean formation. The subterranean formation includes a rock matrix about the wellbore. Shear bands are induced in the rock matrix by communicating the injection fluid from the wellbore into the rock matrix. A chemical treatment fluid is communicated through the shear bands into the matrix. The chemical treatment is conducted from the wellbore primarily by a portion of the rock matrix that forms a wall of the wellbore, primarily by a subset of the shear bands that intersect the wall of the wellbore, or primarily by a combination of them. In some instances, the shear bands may improve uniformity or efficiency of the chemical treatment. | 01-17-2013 |
| 20130020085 | SURFACTANT SYSTEM TO INCREASE HYDROCARBON RECOVERY - A post-primary oil recovery process for recovering oil from a subterranean formation may involve injecting into a crude oil-bearing subterranean formation an aqueous saline surfactant composition of brine, Alkyl Polyglucoside, Linear Primary Alcohol Ethoxylate, sodium hydroxide and alcohols; displacing the aqueous composition through the oil-bearing formation and driving oil from the oil-bearing formation; and recovering oil displaced from the subterranean formation. The injecting step may be preceded by the step of injecting into the subterranean formation a volume of salinity water to adjust salinity of connate water within the subterranean reservoir to a predetermined salinity. Injection of the surfactant composition may further be followed by injection of a buffer comprising water dispersible polymeric viscosifier or water soluble polymeric viscosifier. The surfactant composition may additionally contain at least one cosurfactant selected from hydrocarbon sulfonates and alcohols. The aqueous saline surfactant composition may be or include SCHMOO-B-GONE SURFACTANT®. | 01-24-2013 |
| 20130025866 | INTEGRATED PROCESS UTILIZING NITROGEN AND CARBON DIOXIDE STREAMS FOR ENHANCED OIL RECOVERY - Disclosed is an integrated enhanced oil recovery process and system for use in recovering relatively light oil from an oil-producing reservoir utilizing the injection of nitrogen produced by air separation in a cryogenic air separation unit and/or carbon dioxide produced by combustion in an oxygen fired steam generator fed by oxygen from the air separation unit. The steam produced may be utilized for suitable uses other than injection into an oil-producing reservoir, including heat generation and driving steam turbines, which in turn drive rotary equipment such as electrical generators, pumps and compressors. | 01-31-2013 |
| 20130037270 | APPARATUS, SYSTEM AND METHOD FOR INJECTING A FLUID INTO A FORMATION DOWNHOLE - A method is disclosed, including but not limited to positioning a tool containing an injection liquid in a well bore formed in a formation; injecting the injection liquid through a probe into the formation; and withdrawing formation fluid from the formation through the probe. A system is disclosed for performing functions useful in positioning a tool containing an injection liquid in a well bore formed in a formation; injecting the injection liquid through a probe into the formation; and withdrawing formation fluid from the formation through the probe. | 02-14-2013 |
| 20130048290 | INJECTION OF FLUID INTO SELECTED ONES OF MULTIPLE ZONES WITH WELL TOOLS SELECTIVELY RESPONSIVE TO MAGNETIC PATTERNS - A method of actuating a well tool can include displacing a magnetic device pattern in the well, thereby transmitting a corresponding magnetic signal to the well tool, and the well tool actuating in response to detection of the magnetic signal. A method of injecting fluid into selected ones of multiple zones penetrated by a wellbore can include displacing at least one magnetic device into at least one valve in the wellbore, the valve actuating in response to the displacing step, and injecting the fluid through the valve and into at least one of the zones associated with the valve. An injection valve for use in a subterranean well can include a sensor which detects a magnetic field, and an actuator which opens the injection valve in response to detection of at least one predetermined magnetic signal by the sensor. | 02-28-2013 |
| 20130056211 | POLYAMINE-DIHYDROXYBENZOIC ACID CONJUGATE HYDROGELS AS IRON CHELATORS - Compositions and methods for making a composition comprising a polymer and one or more chelators covalently coupled to polymer, wherein the one or more chelators has a benzene ring with more than one hydroxyl group at any position that is free, or a derivative of the chelator, or a salt of the chelator and methods of use. | 03-07-2013 |
| 20130062066 | Multi-Zone Screened Fracturing System - A multi-zone formation treatment assembly has sections disposed on a tubular structure in a borehole. An isolation element disposed on the tubular structure that isolates a borehole annulus around the section from the other sections, and a flow valve disposed on the tubular structure is selectively operable between opened and closed conditions permitting and preventing fluid communication between the through-bore and the borehole annulus. A screen disposed on the tubular structure communicates with the borehole annulus, and a closure disposed on the tubular structure at least prevents fluid communication from the through-bore to the screen. A workstring of the assembly can be manipulated in the tubular structure relative to each section in the same trip to: open the flow valve, position in the through-bore relative to the open flow valve, deliver the treatment from an outlet to the section through the open flow valve, and close the flow valve. | 03-14-2013 |
| 20130068462 | Increased Resource Recovery by Inorganic and Organic Reactions and Subsequent Physical Actions that Modify Properties of the Subterranean Formation which Reduces Produced Water Waste and Increases Resource Utilization via Stimulation of Biogenic Methane Generation - Methods of resource recovery include reagents placed in a subterranean formation. The reagents generate heat, hydrogen gas and alkalinity which changes fluid flow characteristics. The forces of the reactions create fractures and cracks far from the well bore. These cracks and fractures are sealed if water is being transmitted through or near the reactions. As a result, the targeted fluids more efficiently flow to the well, along with decreased amounts of water waste, while stimulating generation of biogenic gases in the subterranean formations. | 03-21-2013 |
| 20130081817 | Responsively Activated Wellbore Stimulation Assemblies and Methods of Using the Same - A wellbore servicing apparatus comprising a housing substantially defining an axial flowbore and comprising one or more ports, an expandable seat, and a sliding sleeve slideably fitted within the housing, the sliding sleeve being transitional from a first position to a second position and from the second position to a third position, wherein, in the first position, the sliding sleeve does not permit fluid communication via the one or more ports and the expandable seat is retained in a narrower, non-expanded conformation, wherein, in the second position, the sliding sleeve permits fluid communication via the one or more ports and the expandable seat is retained in a narrower, non-expanded conformation, and wherein, in the third position, the sliding sleeve does not permit fluid communication via the one or more ports and the expandable seat is allowed to expand into a wider, expanded conformation. | 04-04-2013 |
| 20130081818 | METHOD EMPLOYING PRESSURE TRANSIENTS IN HYDROCARBON RECOVERY OPERATIONS - The invention relates to methods to induce pressure transients in fluids for use in hydrocarbon recovery operations. The invention is further characterized by inducing the pressure transients in a fluid by a collision process. The collision process employs a moving object ( | 04-04-2013 |
| 20130087338 | WELLBORE OPERATIONS USING CONTROLLED VARIABLE DENSITY FLUID - Fluid systems may contain elements to provide changes in bulk fluid density in response to various environmental conditions. One environmental driver to the variable density is pressure; other environmental drivers include, but are not limited to, temperature or changes in chemistry. The variable density of the fluid is beneficial for controlling sub-surface pressures within desirable pore pressure and fracture gradient envelopes. The variability of fluid density permits construction and operation of a wellbore with much longer hole sections than when using conventional single gradient fluids. | 04-11-2013 |
| 20130087339 | METHOD TO REDUCE GHG EMISSIONS OF FUEL PRODUCTION - The present invention provides a method comprising carrying out an anaerobic digestion that produces biomethane and biogenic carbon dioxide and supplying the biogenic carbon dioxide for use in one or more enhanced oil or gas recovery operations. The biogenic carbon dioxide supplied to the one or more enhanced oil or gas recovery operations displaces the use of geologic carbon dioxide. Further provided is a method to reduce the life cycle GHG emissions associated with the production of a liquid fuel or fuel intermediate in a fuel production facility by providing such biomethane for use in the fuel production facility or associated utilities to supply energy. The present invention also relates to a method for receiving carbon dioxide at an enhanced oil or gas recovery site that has the GHG emission attributes of the biogenic carbon dioxide and using the received carbon dioxide to displace geologic carbon dioxide. | 04-11-2013 |
| 20130098618 | HYDROPHOBICALLY MODIFIED POLYMER FOR THERMALLY STABILIZING FRACTURING FLUIDS - A method for treating a zone of subterranean formation is provided. The method includes the steps of: (a) forming a treatment fluid including: (i) water; (ii) a viscosity-increasing agent selected from the group consisting of water-soluble polysaccharides, water-soluble derivatives thereof, and any combination of the foregoing; (iii) a crosslinker for the viscosity-increasing agent; (iv) a hydrophobically modified water-soluble polymer; wherein the viscosity-increasing agent is not a hydrophobically modified polymer; and (b) introducing the treatment fluid into a zone of a subterranean formation, wherein the zone has a design temperature of equal to or greater than 350° F. | 04-25-2013 |
| 20130098619 | SPLIT STREAM OILFIELD PUMPING SYSTEMS - A method of pumping an oilfield fluid from a well surface to a wellbore is provided that includes providing a clean stream; operating one or more clean pumps to pump the clean stream from the well surface to the wellbore; providing a dirty stream including a solid material disposed in a fluid carrier; and operating one or more dirty pumps to pump the dirty stream from the well surface to the wellbore, wherein the clean stream and the dirty stream together form said oilfield fluid. | 04-25-2013 |
| 20130098620 | FLOW RATE CONTROL VALVE FOR SOLUTIONS OF POLYMERS - The disclosure relates to a method for injecting a fluid into an underground formation, wherein:
| 04-25-2013 |
| 20130105164 | HIGH ENERGY IN-LINE HYDRAULIC SHEARING UNIT FOR OILFIELD DRILLING FLUIDS | 05-02-2013 |
| 20130105165 | HYDROPHOBICALLY ASSOCIATING COPOLYMERS | 05-02-2013 |
| 20130112415 | Compositions and Methods for Protecting Metal Surfaces from Corrosion - Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers. | 05-09-2013 |
| 20130112416 | Compositions and Methods for Protecting Metal Surfaces from Corrosion - Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers. | 05-09-2013 |
| 20130112417 | Compositions and Methods for Protecting Metal Surfaces from Corrosion - Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers. | 05-09-2013 |
| 20130112418 | Composition and Methods for Protecting Metal Surfaces from Corrosion - Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers. | 05-09-2013 |
| 20130118747 | Cleanup Fluids for Anhydrous Borate Compounds and Methods for Use Thereof in Subterranean Formations - Anhydrous borate compounds can be used in a variety of subterranean treatment operations, where particulates of the anhydrous borate compounds slowly become soluble in an aqueous fluid after facilitating the treatment operation. Cleanup fluids can be used for affecting a more rapid removal of the anhydrous borate compounds from a subterranean formation. Methods for performing a cleanup of anhydrous borate compounds within a subterranean formation can comprise providing a cleanup fluid comprising a polyhydroxylated compound, introducing the cleanup fluid into a subterranean formation having a plurality of anhydrous borate particulates therein, and interacting the polyhydroxylated compound with the anhydrous borate particulates such that the anhydrous borate particulates become soluble in an aqueous fluid. | 05-16-2013 |
| 20130118748 | Gelled Foam Compositions And Methods - The invention provides a method made of steps of injecting into a wellbore, a composition comprising a solvent, a surfactant, a foaming gas, a foam enhancer, a crosslinkable polymer, and a crosslinking agent capable of crosslinking the polymer, wherein the foam enhancer increases the foam half-life of the gel composition compared to the gel composition without the foam enhancer; and allowing viscosity of the composition to increase and form a gel. | 05-16-2013 |
| 20130118749 | Rotating Control System and Method for Providing a Differential Pressure - A Drill-To-The-Limit (DTTL) drilling method variant to Managed Pressure Drilling (MPD) applies constant surface backpressure, whether the mud is circulating (choke valve open) or not (choke valve closed). Because of the constant application of surface backpressure, the DTTL method can use lighter mud weight that still has the cutting carrying ability to keep the borehole clean. The DTTL method identifies the weakest component of the pressure containment system, such as the fracture pressure of the formation or the casing shoe leak off test (LOT). With a higher pressure rated RCD, such as 5,000 psi (34,474 kPa) dynamic or working pressure and 10,000 psi (68,948 kPa) static pressure, the limitation will generally be the fracture pressure of the formation or the LOT. In the DTTL method, since surface backpressure is constantly applied, the pore pressure limitation of the conventional drilling window can be disregarded in developing the fluid and drilling programs. Using the DTTL method a deeper wellbore can be drilled with larger resulting end tubulars, such as casings and production liners, than had been capable with conventional MPD applications. | 05-16-2013 |
| 20130126172 | METHOD OF MAKING CARBON DIOXIDE - Carbon dioxide free of many impurities is formed by combusting syngas with oxygen and controlling the amount of oxygen combined with the syngas so that the produced combustion gas has less than 2% unreacted oxygen. The syngas can be formed in a horizontal reactor | 05-23-2013 |
| 20130126173 | Cement Head - A method of assembling a wellbore servicing tool, comprising placing a first module adjacent to a second module along an axis, engaging a bridge with each of the first module and the second module by, while the bridge radially overlaps one of the first module and second module, substantially restricting movement of the bridge to movement radially toward the first module and the second module and toward the axis. A method of assembling a wellbore servicing tool, comprising angularly aligning a first module with a second module, joining the first module to the second module while maintaining the angular alignment between first module and the second module. A method of assembling a wellbore servicing tool, comprising assembling a cement head without using torque to join components of the cement head, and passing a fluid through the cement head into a wellbore. | 05-23-2013 |
| 20130133890 | ALKALINE PERSULFATE FOR LOW-TEMPERATURE BREAKING OF MULTI-CHAIN POLYMER VISCOSIFIED FLUID - A persulfate compound activated by a strong base is used for low-temperature breaking of fluids viscosified with a multi-chain polysaccharide. The breaker system can be used in an oilfield or pipeline application where a multi-chain polysaccharide may be used in a fluid. It is particularly useful at low temperatures of less than 100° F. Optionally, the water can be a brine. | 05-30-2013 |
| 20130140028 | WELLBORE CLEANING APPARATUS AND METHOD - A debris collecting tool for use within a wellbore is provided. The tool comprises a filter body having an upstream end and a downstream end. A first fluid passage extends longitudinally between the upstream and downstream ends of the filter body, and at least one second fluid passage connects the first fluid passage with the exterior of the filter body. A filter is located between the first fluid passage and the at least one second fluid passage. The tool further comprises a flow controller movable between a first position in which fluid is prevented from entering the at least one second fluid passage from the exterior of the filter body, and a second position in which fluid is permitted to enter the at least one second fluid passage from the exterior of the filter body. An agitator body is attached to the upstream end of the filter body, and includes at least one radially projecting agitation member. Methods of using the tool to collect debris and clean a wellbore are also provided. | 06-06-2013 |
| 20130140029 | TORQUE LIMITING DEVICE - A work string assembly for an oil or gas well has a first and second tubulars, and a torque limiting device connected in the work string. The torque limiting device has a body with an axial bore and two interconnected members that can disconnect to be relatively rotatable. The interconnected members can be repeatedly re-engageable when the torque levels drop below a torque threshold value, or can be connected by a frangible member that is broken when the interconnected members disconnect. A selectively actuable circulation port provided in the string adjacent to and above the torque limiting device allows the annulus between the work string and the casing to be flushed with fluid from the port. | 06-06-2013 |
| 20130140030 | Apparatus and method for dispensing chemicals into a well - A well chemical dispensing system includes a tubular sub for securing into a drill string. A ball stop is located within the passage. A ball filled with a liquid surfactant is pumped down the well. The ball is formed of a frangible material for shattering on impact with the ball stop, so as to dispense the surfactant, causing foaming when mixing with well fluid. Struts within the ball extend across an interior of the ball and join to inner surfaces of the ball. The struts are formed of a solid surfactant material. The ball has a spherical shape with dimples formed in an exterior surface of the sphere. A spring in the passage applies an upward force on the ball stop. The ball stop has upper and lower grids extending across the passage. | 06-06-2013 |
| 20130146290 | SELECTIVE PLACEMENT OF CONFORMANCE TREATMENTS IN MULTI-ZONE WELL COMPLETIONS - Selective placement of conformance treatments in multi-zone well completions. A method includes injecting a relative permeability modifier into a zone and optimizing a ratio of desired fluid to undesired fluid produced from the zone, including adjusting at least one flow control device between fully open and fully closed configurations. Another method includes injecting a relative permeability modifier into multiple zones, one at a time, via respective flow control devices, and then producing fluid from each of the zones. Another method includes identifying which of the zones to treat by, for each of the zones: a) closing flow control devices corresponding to the other zones, and b) evaluating fluid produced from the zone; and injecting a conformance treatment into the zones identified as the zones to treat. | 06-13-2013 |
| 20130153231 | AUTOMATIC CHEMICAL TREATMENT SYSTEM WITH LIQUID LEVEL SENSOR IN CHEMICAL TANK FOR CALIBRATION AND CHEMICAL DISPENSING RATE CONTROL - 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. | 06-20-2013 |
| 20130153232 | METHODS AND COMPOSITIONS FOR REDUCING PERMEABILITY OF A SUBTERRANEAN FORMATION - The present application is directed to an aqueous composition made up of an alkali metal silicate; a hardener containing at least one dibasic ester, at least one nonionic surfactant, at least one terpene or terpene derivative and optionally at least one polyalkylene glycol; and a retarder. The composition is useful for reducing the permeability in a subterranean formation, so as to reduce or prevent water flow and circulation loss of well fluids such as drilling fluids or cement. | 06-20-2013 |
| 20130161010 | OIL RECOVERY PROCESS - The present invention provides a method for enhancing the recovery of oil from a formation. A hydrocarbon-containing gas and an ether are injected into an oil-bearing formation to mobilize the oil. The mobilized oil is then produced from the formation. | 06-27-2013 |
| 20130168095 | IODIDE STABILIZER FOR VISCOSIFIED FLUID CONTAINING IRON - A composition of a treatment fluid and method for treating a zone of well. In an embodiment, the composition includes at least: (i) an aqueous phase; (ii) at least 5 ppm iron ion in the aqueous phase; (iii) a source of at least 5 ppm iodide ion to be dissolved in the aqueous phase; (iv) a water-soluble viscosity-increasing agent dissolved in the aqueous phase; and (v) a source of an oxidative breaker to be dissolved in the aqueous phase. In an embodiment, a method of treating a zone of a subterranean formation of a well includes at least the steps of: (a) forming a treatment fluid according to the composition; and (b) introducing the treatment fluid into the zone. | 07-04-2013 |
| 20130168096 | Additive to Fluid for The Treatment of Subterranean Formation and A Method for Treating Subterranean Formation - The composition includes a pH adjusting agent and a precipitation-control agent. The pH adjusting agent provides the hydrolysis of degradable fibers at a temperature of no more than 50° C. and comprises substances that may provide and maintain a high pH environment. The precipitation-control agent allows maximally delaying or completely suppressing the formation and deposition of precipitate during the hydrolysis of the degradable components in the treatment fluid A method of treating an subterranean formations penetrated by a wellbore with the additives described herein comprises providing a treatment fluid comprising a base mixture and a degradable substance, with additionally added degradable materials, and injecting the prepared treatment fluid into the subterranean formation. | 07-04-2013 |
| 20130168097 | METHOD AND SYSTEM FOR ENHANCING OIL RECOVERY (EOR) BY INJECTING TREATED WATER INTO AN OIL BEARING FORMATION - A process and a system for enhancing recovery of oil from an oil-bearing formation are provided in which water having a total dissolved solids content is filtered to remove some solids in a filter assembly, the filtered water is treated to remove some ions in a capacitive deionization assembly, and the filtered deionized water is injected into the oil-bearing formation to mobilize crude oil and enhance oil recovery from the formation. | 07-04-2013 |
| 20130175037 | METHOD OF CONTROLLING RESERVOIR PARTICLES USING ELECTROLYTIC COMPOSITE MATERIALS - A method of reducing the presence of particles in a downhole environment, comprising contacting sediment particles contained in a downhole environment, with a composition comprising: a metallic composition, an inorganic oxide-based polymer, and a solvent; the contacting occurring in the presence of a fluid capable of decomposing the metallic composition | 07-11-2013 |
| 20130180718 | METHOD AND APPARATUS FOR WELLBORE FLUID TREATMENT - A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in in a pressure tight condition and later is needed to be in an open-port condition. | 07-18-2013 |
| 20130180719 | METHOD FOR AUTONOMOUS CONTROL OF A CHEMICAL INJECTION SYSTEM FOR OIL AND GAS WELLS - A control program for a positive displacement metering system measures the time required for the travel of a free piston in a cylinder of known volume to determine an average flow rate during a full stroke of the piston. The system may also measure and record the inlet and outlet pressures or the differential pressure between the fluid inlet and outlet. The control program positions a four-way valve which may function as an adjustable metering orifice in response to the measured average flow rate and/or changes in the inlet and outlet pressures to achieve the desired flow rate. At the end of each stroke, the four-way valve is repositioned to reverse fluid flow through the metering cylinder. The system may revise the valve position settings for both forward and reverse strokes based on the measured time required for a full stroke at a certain valve position. In this way, the system automatically and iteratively compensates for changes in fluid properties and fluid pressure. A cleaning cycle which progressively opens the valve stepwise and may culminate in full open valve travel in both fluid flow directions is provided in the event of an obstruction of the valve orifice. | 07-18-2013 |
| 20130186628 | DOWNHOLE TOOL HYDRAULIC RETRIEVER - A downhole tool hydraulic retriever is provided that includes a stroking unit comprising a hydraulic cylinder, a piston body at least partially disposed within the hydraulic cylinder, and a piston rod extending from the piston body. The downhole tool hydraulic retriever also includes first and second packer cup assemblies configured to translate axially with respect to each other. In addition, the downhole tool hydraulic retriever includes a pressure intensification module comprising sequencing valves and hydraulic distribution lines configured to divert pressure to the first packer cup assembly when the piston body is at a beginning of a stroke within the hydraulic cylinder, and to divert pressure to the second packer cup assembly when the piston body is at an end of the stroke within the hydraulic cylinder. | 07-25-2013 |
| 20130186629 | Asphaltene Inhibitors for Squeeze Applications - Reaction products of polymeric alkyl phenol formaldehyde resins are useful as additives to inhibit or prevent the deposition or precipitation of asphaltenes in hydrocarbon fluids, particularly crude oil produced from a subterranean formation. These reaction products are formed by reacting a polymeric alkyl phenol formaldehyde resin with a co-reactant having functional groups including, but not necessarily limited to, amines, esters, silanes, ketones, epoxides, alkoxides, aryloxides, halogens, alkali metals, alkali earth metals, acetamides, non-metal oxides, metal oxides, where the co-reactant optionally has a carbon chain length between 1 and 22 and the reaction is conducted in the presence of at least one of various solvents. In one non-limiting embodiment, the co-reactant is a silicon derivative. The asphaltene inhibitors have utility when injected into a subterranean formation while oil production temporarily halts, a process called “squeezing,” because they are retained to a degree in the formation as the crude oil is produced. | 07-25-2013 |
| 20130192835 | METHOD OF REDUCING DUST WITH SELF-ASSEMBLY COMPOSITES - Well treatment particulates are coated with polyionic material and a composite is formed comprising multiple layers of polyelectrolyte, each layer composed of polyionic material counter to the polyionic material of the polyelectrolyte layer to which it is adjacent. | 08-01-2013 |
| 20130192836 | WATER TREATMENT IN AT LEAST ONE MEMBRANE FILTRATION UNIT FOR ASSISTED RECOVERY OF HYDROCARBONS - A water treatment method includes:
| 08-01-2013 |
| 20130199788 | METHOD AND COMPOSITION FOR ENYHANCED HYDROCARBONS RECOVERY - A method of treating a formation containing crude oil is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of a formation containing crude oil wherein the composition comprises a high molecular weight internal olefin sulfonate and a viscosity reducing compound; and (b) allowing the composition to interact with hydrocarbons in the crude oil containing formation. | 08-08-2013 |
| 20130199789 | Method and System for Fracturing a Formation - Systems and methods are described for fracturing a production formation. A method includes drilling a well into a zone proximate to a production formation, and increasing a volume of the zone through the well in order to apply a mechanical stress to the production formation. | 08-08-2013 |
| 20130199790 | WIRELINE CONVEYED APPARATUS FOR WELLBORE FLUID TREATMENT - 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. | 08-08-2013 |
| 20130206414 | SYSTEM AND METHOD FOR PRE-CONDITIONING A HYDRATE RESERVOIR - A method of drilling into a geological region including a subsurface clathrate reservoir includes drilling a borehole into the geological region including the subsurface clathrate reservoir and dissociating at least a portion of the clathrate in a region near the borehole. After the dissociating, material within at least a portion of the region near the borehole in which the clathrate has been dissociated is compacted to form a compacted region at least partially surrounding the borehole within the clathrate reservoir. After the compacting, well casing is placed into the borehole within the compacted region and the well casing is cemented into the borehole in the compacted area. | 08-15-2013 |
| 20130228335 | Methods, Systems, and Compositions for the Controlled Crosslinking of Well Servicing Fluids - Treating fluid compositions for use in hydrocarbon recovery operations from subterranean formations are described, as well as methods for their preparation and use. In particular, treating fluid compositions are described which comprise a liquid, a crosslinkable organic polymer material that is at least partially soluble in the liquid, a crosslinking agent that is capable of increasing the viscosity of the treating fluid by crosslinking the organic polymer material in the liquid, and a crosslinking modifier additive which can delay or accelerate the crosslinking of the treating fluid composition. Such compositions may be used in a variety of hydrocarbon recovery operations including fracturing operations, drilling operations, gravel packing operations, water control operations, and the like. | 09-05-2013 |
| 20130228336 | Methods for Servicing Subterranean Wells - Methods for controlling fluid flow through one or more pathways in one or more rock formations penetrated by a borehole in a subterranean well, comprise injecting into or adjacent to the formation a treatment fluid comprising at least one viscoelastic surfactant; fibers, or a mixture of fibers and particles; and one or more flocculation initiators. Flocculation of the mixture produces fibrous masses that migrate to formation-rock openings such as pores, cracks, fissures and vugs. As a result, the fibrous masses are useful for curing lost circulation, providing fluid-loss control and as diverting agents. | 09-05-2013 |
| 20130233557 | BOTTOMHOLE ASSEMBLY FOR CAPILLARY INJECTION SYSTEM - A method of treating production fluid in a wellbore includes deploying a capillary string into the wellbore. The capillary string has a plurality of injection valves. The method further includes pumping treatment fluid through the capillary string and into the wellbore. The injection valves have a cumulative set pressure greater than or equal to a hydrostatic pressure of the treatment fluid. | 09-12-2013 |
| 20130233558 | Methods for Servicing Subterranean Wells - Methods for controlling fluid flow through one or more pathways in one or more carbonate-rock formations penetrated by a borehole in a subterranean well, comprise injecting into or adjacent to the formation a treatment fluid comprising at least one viscoelastic surfactant; fibers, or a mixture of fibers and particles; and at least one acid. The initial fluid viscosity is sufficient to transport the fibers and particles; however, upon reacting with the carbonate rock, the fluid viscosity falls. The lower fluid viscosity promotes efficient fiber bridging across the pathways, thereby providing diversion. | 09-12-2013 |
| 20130240209 | Cold Distillation Process and Apparatus - Apparatus and method for economically removing salts and heavy metals from water. The apparatus and method provide for flowing of the water across a transducer/resonator assembly which has enhanced resonation such that the water vaporizes and condenses without the salts or heavy metals. The water may then be used for drinking, irrigation, agricultural purposes, or injecting into subterranean formations related to mining or the recovery of hydrocarbons. The water may also be used to supplement or prepare water for reverse-osmosis desalination processes. | 09-19-2013 |
| 20130240210 | Systems and Methods For Injecting A Particulate Mixture - An embodiment of the present techniques provides a method of injecting a particulate mixture into a target location. The method includes forming a mixture of at least two sources of particles with different size distributions wherein the mixture of solids has a permeability in a predefined range. A water content of the mixture is varied to control the rheology of the mixture. The particles are injected through one or more pipes into a target location. | 09-19-2013 |
| 20130248187 | INFLATABLE COLLAR AND DOWNHOLE METHOD FOR MOVING A COILED TUBING STRING - An elongated inflatable collar is securely attached to the exterior surface of a coiled tubing string before the tubing is lowered into the well for subsequent positioning at a predetermined subterranean location in the well casing. Upon inflation, the inflatable collar seals the annulus between the coiled tubing string and the well casing. A liquid injected from the surface creates sufficient hydraulic pressure on the upper surface of the inflated collar to advance the collar and the attached coiled tubing string and overcome frictional drag forces with the surrounding wall that caused the coiled tubing string to lock-up. The inflatable collar of the present invention can also be used to free a section of coiled tubing that is jammed in the formation due to buckling, by injecting a pressurized liquid into the wellbore downstream of the inflated collar to thereby apply a force to the downhole surface of the collar. | 09-26-2013 |
| 20130248188 | IN-SITU SELF DIVERTING WAG PROCESS - An aqueous viscoelastic solution for use in a modified water alternating gas (WAG) hydrocarbon production method includes a viscoelastic surfactant and a salt in an aqueous base solution. A modified water alternating gas (WAG) method for producing hydrocarbons from a hydrocarbon-bearing formation includes the step of introducing the aqueous viscoelastic solution into the hydrocarbon-bearing formation. The method also includes the step of introducing a service gas into the hydrocarbon-bearing formation. The aqueous viscoelastic solution and the service gas are introduced separately and sequentially into the hydrocarbon-bearing formation. The hydrocarbon-bearing formation produces a production fluid in response to each introduction. The production fluid contains both water and hydrocarbons. | 09-26-2013 |
| 20130255951 | Compositions, Systems and Methods for Releasing Additive Components - Compositions, systems and methods for the controlled and/or delayed release of chemical additive components into an aqueous fluid used in hydraulic fracturing of oil and/or gas wells. The chemical additive components may include a viscosity-reducing composition, an oxidizer composition, a pH modulating composition, a lubricant composition, a cross-linking composition, an anti-corrosion composition, an biocide composition, a crosslink-enhancing composition, and/or a combination of two or more of these compositions. Further embodiments include additives and methods of delivering a particle comprising an additive component to a desired site in an aqueous medium prior to release of the additive component into the aqueous medium. The coating is permeable, but insoluble in an aqueous medium, whereupon the additive components are released into the medium. | 10-03-2013 |
| 20130255952 | Controlled Production and Injection - A well production and injection string includes a plurality of spaced apart packers each adapted to seal with a wall of the wellbore. A plurality of flow control devices are provided in the string, distributed between pairs of adjacent packers. The flow control devices are adapted to communicate flow between an interior and an exterior of the string with less restriction to flow from the interior to the exterior of the string than to flow from the exterior to the interior of the string. | 10-03-2013 |
| 20130264059 | USE OF PERACETIC ACID/HYDROGEN PEROXIDE AND PEROXIDE-REDUCING AGENTS FOR TREATMENT OF DRILLING FLUIDS, FRAC FLUIDS, FLOWBACK WATER AND DISPOSAL WATER - Methods for the use of peracid compositions having decreased hydrogen peroxide concentration and a UV-blocking agent for various water treatments, including oil- and gas-field operations, and/or other aseptic treatments are disclosed. In numerous aspects, peracetic acid is the preferred peracid and is treated with a peroxide-reducing agent to substantially reduce the hydrogen peroxide content. Methods for using the treated peracid compositions for treatment of drilling fluids, frac fluids, flow back waters and disposal waters are also disclosed for improving water condition, reducing oxidizing damage associated with hydrogen peroxide and/or reducing bacteria infestation | 10-10-2013 |
| 20130264060 | FLUID SUITABLE FOR TREATMENT OF CARBONATE FORMATIONS CONTAINING A CHELATING AGENT - The present invention covers a fluid and kit of parts suitable for treating carbonate formations containing glutamic acid N,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N,N-diacetic acid or a salt thereof (MGDA), a corrosion inhibitor, and a surfactant, and the use thereof. | 10-10-2013 |
| 20130269944 | Treatment Fluids Comprising an Alkali Metal Complexing Agent and Methods for Use Thereof - Alkali metal ions may lead to the production of insoluble materials during the course of stimulating a subterranean formation, particularly when acidizing a siliceous formation or a formation containing a siliceous material. Alkali metal ions may be sequestered using an alkali metal complexing agent in order to reduce their propensity toward forming insoluble materials in a subterranean formation. Methods for stimulating a subterranean formation can comprise: providing a treatment fluid that comprises an alkali metal complexing agent comprising a cyclic polyether having between 3 and 6 ether oxygen atoms present therein, and hydrofluoric acid, a hydrofluoric acid-generating compound, or any combination thereof; and introducing the treatment fluid into a subterranean formation. | 10-17-2013 |
| 20130277055 | METHOD FOR THE ASSISTED RECOVERY OF PETROLEUM - The invention relates to a method for the assisted recovery of petroleum in a deposit by means of the introduction of an aqueous solution of a hydrosoluble polymer into the deposit, said method being characterised in that said aqueous solution is prepared by dissolving a polymer-based composition containing at least one hydrosoluble polymer, at least one radical capturing agent, and at least one sacrificial agent, in an aqueous solution subjected to a step of treatment with at least one deoxygenating agent, prior to the introduction of the polymer-based composition. | 10-24-2013 |
| 20130306317 | DEGRADABLE POLYMER AND LEGUME PARTICULATES FOR WELL TREATMENT - A method of treating a treatment zone in a well is provided, the method including the steps of: (A) forming a treatment fluid comprising: (i) a degradable polymer particulate; (ii) a legume particulate; and (iii) a continuous liquid phase; and (B) introducing the treatment fluid into the treatment zone of the well. The invention can be used, for example, for leak-off control or fluid diversion purposes. | 11-21-2013 |
| 20130306318 | EROSION REDUCTION IN SUBTERRANEAN WELLS - A system for use with a subterranean well can include a tubular string with a fluid discharge apparatus, the fluid discharge apparatus including a curved flow path which directs a fluid to flow less toward a structure external to the tubular string. A fluid discharge apparatus can include a generally tubular housing having a longitudinal axis, and at least one curved flow path which directs fluid to flow more parallel to the longitudinal axis from an interior of the housing to an exterior of the housing. A method of mitigating erosion of a structure external to a discharge port in a well can include directing a fluid to flow through a curved flow path, thereby reducing impingement of the fluid on the structure in the well. | 11-21-2013 |
| 20130306319 | Hydraulic Pulse Valve With Improved Pulse Control - Hydraulic pulses are produced each time that a pulse valve interrupts the flow of a pressurized fluid through a conduit. The pulse valve includes an elongate housing having an inlet configured to couple to the conduit to receive the pressurized fluid, and an outlet configured to couple to one or more tools. In the housing, a valve assembly includes a poppet reciprocating between open and closed positions, and a poppet seat, in which the poppet closes to at least partially block the flow of pressurized fluid through the valve. A pilot within the poppet moves between disparate positions to modify fluid paths within the valve. When the valve is open, a relatively lower pressure is produced by a Venturi effect as the fluid flows through a throat in the poppet seat, to provide a differential pressure used to move the pilot and poppet. An optional bypass reduces the pulse amplitude. | 11-21-2013 |
| 20130312970 | THICKENING OF FLUIDS - An aqueous fluid contains an aqueous solution or dispersion of a polymer to thicken the fluid together with a cross linking agent to enhance the viscosity of the fluid by crosslinking the polymer, wherein the crosslinking agent comprises supporting structures bearing functional groups to react with the polymer molecules and has a mean particle size of 2 nanometer or more. The supporting structures may be nanoparticles and the functional groups may be boronic acid groups. The concentration of boron in a thickened fluid may be low and in some instances there is resistance to applied pressure. The fluid may be a hydraulic fracturing fluid. | 11-28-2013 |
| 20130319676 | WELLBORE FLUID TREATMENT PROCESS AND INSTALLATION - A method for isolating a perforated interval of a well, the well including a casing liner having a wall with a plurality of perforations therethrough forming the perforated interval, the method comprising: providing a tool including a tubular body including an inner diameter and an outer surface, a first open end and a second open end, the first and second open ends providing access to the inner diameter; and a sealing element to isolate a mid region of the outer surface from the first open end and the second open end; positioning the tool in the well with the tubular first open end adjacent and above an uppermost perforation of the perforated interval and the second open end adjacent and below a lowermost perforation of the perforated interval; and installing the tool in the well with the sealing element sealing between the tubular body and the casing wall above the uppermost perforation of the perforated interval and below the lowermost perforation of the perforated interval to isolate fluid flow between the perforations and the inner diameter. | 12-05-2013 |
| 20130341028 | CONTROLLABLY TUNING PROPERTIES OF A FLUID USING MODIFIED NANOPARTICLES - Properties of a base fluid may be controllably tuned to a pre-determined range of measurements by adding modified nanoparticles to a base fluid. The property to be modified may be or include, but is not limited to, electrical conductivity, dielectric strength, thermal conductivity, and combinations thereof. The modified nanoparticles may be or include modified graphene nanoparticles, modified graphene platelets, modified electrically-conductive nanotubes, modified electrically-conductive nanorods, nanospheres, single-walled nanotubes, double walled nanotubes, multiwalled nanotubes, nano-onions, fullerenes, nanodiamonds, and combinations thereof. The base fluid may be or include, but is not limited to a non-aqueous based fluid, an aqueous fluid, and combinations thereof. | 12-26-2013 |
| 20140008070 | PULSATING ROTATIONAL FLOW FOR USE IN WELL OPERATIONS - 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. | 01-09-2014 |
| 20140014344 | Method and System for Servicing a Wellbore - A method of servicing a wellbore, comprising transporting a fluid treatment system to a wellsite, accessing a water source proximate to the wellsite, introducing a water stream from the water source into the fluid treatment system, irradiating at least a portion of the water stream within the fluid treatment system, wherein the portion of the water stream is irradiated by exposing the portion of the water stream to ultraviolet light emitted from at least one pulsed ultraviolet lamp, forming a wellbore servicing fluid from the irradiated water stream, and placing the wellbore servicing fluid into the wellbore. | 01-16-2014 |
| 20140014345 | Check Valve for Well Stimulation - Check valve assemblies operable to inject treatment fluids during stimulation operations are described. One check valve assembly includes a valve body defining an inlet, one or more discharge ports, and a cylindrical passageway fluidly communicating the inlet with the one or more discharge ports, the valve body further defining a valve body seat within the passageway. A valve cap is configured to be coupled to the valve body and defines an opening therein that fluidly communicates with the cylindrical passageway, the valve cap further providing a valve cap seat. A spherical piston is disposed within the passageway and movable between a closed configuration where the spherical piston engages the valve body seat and an open configuration where the spherical piston engages the valve cap seat and allows fluid communication between the inlet and the one or more discharge ports. | 01-16-2014 |
| 20140020899 | FLOODING OPERATIONS EMPLOYING CHLORINE DIOXIDE - A method includes introducing a treatment fluid including a first polymer gel into a subterranean formation to generate a production fluid having an aqueous portion and a hydrocarbon portion, treating the aqueous portion of the production fluid with chlorine dioxide to separate additional hydrocarbons from the aqueous portion, and adjusting the viscosity of the treated aqueous portion prior to introducing the treated aqueous portion back into the subterranean formation. | 01-23-2014 |
| 20140034319 | Method and Wellbore Servicing Apparatus for Production Completion of an Oil and Gas Well - A method of servicing a subterranean formation comprising placing a wellbore servicing system within a wellbore penetrating the subterranean formation, wherein the wellbore servicing system comprises a first activatable stimulation assembly and a second activatable stimulation assembly incorporated within a tubular string, configuring the wellbore servicing system to provide a route of fluid communication from the first activatable stimulation assembly to a first zone of the subterranean formation, introducing a treatment fluid into the first zone of the subterranean formation via the first activatable stimulation assembly, and embedding a first portion of the wellbore servicing system within the wellbore. | 02-06-2014 |
| 20140034320 | HIGH SOLIDS CONTENT FLUID HAVING DEGRADABLE OIL - A fluid comprising a plurality of particulates having an Apollonian particle size distribution dispersed in a carrier fluid optionally comprising a surfactant, the particulates, the carrier fluid, or both comprising a degradable oleaginous fluid. Methods to utilize the fluid are also disclosed. | 02-06-2014 |
| 20140034321 | Carbon Dioxide Fractionalization Process - A process comprising receiving a hydrocarbon feed stream comprising carbon dioxide, separating the hydrocarbon feed stream into a light hydrocarbon stream and a heavy hydrocarbon stream, separating the light hydrocarbon stream into a carbon dioxide-rich stream and a carbon dioxide-lean stream, and feeding the carbon dioxide-lean stream into a hydrocarbon sweetening process, thereby increasing the processing capacity of the hydrocarbon sweetening process compared to the processing capacity of the hydrocarbon sweetening process when fed the hydrocarbon feed stream. Included is an apparatus comprising a first separation unit that receives a hydrocarbon feed stream containing carbon dioxide and produces a heavy hydrocarbon stream and a light hydrocarbon stream, and a second separation unit that receives the light hydrocarbon stream and produces a carbon dioxide-rich stream and a carbon dioxide-lean stream, wherein the apparatus is configured to feed the carbon dioxide-lean stream to a physical solvent, membrane, or carbon dioxide recovery process. | 02-06-2014 |
| 20140041874 | Wellbore Servicing System and Methods of Use - A wellbore servicing system comprising a flowpath comprising a first conduit from a water source to a mixer, a first fluid stream being communicated via the first conduit, the mixer, a wellbore servicing fluid being mixed within the mixer, and a second conduit from the fluid mixer to a wellbore, a wellbore servicing fluid stream being communicated via the second conduit, wherein at least a portion of the first fluid stream, the wellbore servicing fluid, the wellbore servicing fluid stream, or combinations thereof, are in contact with a quantity of template-assisted crystallization beads. | 02-13-2014 |
| 20140041875 | ALKYLARYL SULPHONATE COMPOSITIONS AND USE THEREOF FOR THE ENHANCED RECOVERY OF HYDROCARBONS - A surfactant composition includes an alkaryl sulphonate compound (a) and an alkaryl sulphonate compound (b). The difference between the optimum salinity of compound (a) and the optimum salinity of compound (b) is greater than or equal to 3 g/L. The surfactant composition can easily be adapted to various operating conditions, and in particular to various conditions of salinity, in order to provide optimum enhanced oil recovery. | 02-13-2014 |
| 20140048269 | Fluid Injection System and Method - A system for injecting fluids into a well having a fluid supply tine that is connected to a mandrel at the top of the production tree. The system is designed so that all components of the system are packaged together and run to the production tree in one run. The production tree is designed to provide a pathway for the fluid to travel from the mandrel to the production bore within the tree, and then into the production tubing of a well. | 02-20-2014 |
| 20140060841 | FLUOROUS ADDITIVES FOR USE IN A FLUOROUS-BASED TREATMENT FLUID - 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. | 03-06-2014 |
| 20140069650 | METHOD AND APPARATUS FOR CENTRIFUGAL BLENDING SYSTEM - Blending particulate and liquid to make slurry for use in oilfield operations is addressed. The blender has an upwardly facing particulate expeller with a flat base, raised hub, and generally radially extending, circumferentially spaced vanes extending upwardly from the base. The vanes extend from leading edges spaced about a vane inner diameter to tips spaced about a vane outer diameter. Adjacent expeller vanes define expeller passageways therebetween. The particulate expeller does not serve as a meaningful liquid impeller and the blender does not act significantly as a pump. The expeller has a several preferred diameter, clearance, height and length dimensions and ratios. Wide, deep expeller inlets and shallow, narrow outlets enhance particulate entry and minimize expeller torque. Vane extensions impart velocity to the particulate upon contact and minimize sensitivity to particulate entry velocity. Maximized circumferential overlap of adjacent vanes reduces liquid back-flow. | 03-13-2014 |
| 20140069651 | SPLIT STREAM OILFIELD PUMPING SYSTEMS - A method of pumping an oilfield fluid from a well surface to a wellbore is provided that includes providing a clean stream; operating one or more clean pumps to pump the clean stream from the well surface to the wellbore; providing a dirty stream including a solid material disposed in a fluid carrier; and operating one or more dirty pumps to pump the dirty stream from the well surface to the wellbore, wherein the clean stream and the dirty stream together form said oilfield fluid. | 03-13-2014 |
| 20140076568 | USE OF AQUEOUS ALKALI ALUMINOSILICATE FOR PROFILE MODIFICATION, WATER CONTROL AND STABILIZATION - Embodiments of the invention relate to methods for making and compositions including aqueous alkali aluminosilicates used for conformance. The aqueous alkali aluminosilicates provide similar reaction characteristics of alkali silicates, an in addition provide enhanced conformance properties due to their ability to crystallize. | 03-20-2014 |
| 20140076569 | PROPPANT MIXING AND METERING SYSTEM - An oilfield material reservoir is disclosed. The oilfield material reservoir has a body, the body having an upper end, a lower end, a sidewall extending between the upper and lower ends, the sidewall defining a recess within the body, an opening defined by the upper end, and a first orifice defined by the lower end. The oilfield material reservoir is also provided with a metering gate connected to the body at the lower end. The metering gate has a base having a second orifice aligned with the first orifice, and a knife gate connected to the base. The second orifice has a substantially trapezoidal shape. The knife gate is configured to slidably cover the second orifice. A method is also disclosed for controlling a discharge rate of oilfield material within the oilfield material reservoir by adjusting a metering open area of the second orifice according to mathematical modeling equations. | 03-20-2014 |
| 20140083704 | METHOD FOR REDUCING CONING IN OIL WELLS BY MEANS OF MICRO (NANO) STRUCTURED FLUIDS WITH CONTROLLED RELEASE OF BARRIER SUBSTANCES - The present invention relates to a method for reducing the coning in an oil well of an underground reservoir delimited by an aquifer which comprises an injection phase of a micro(nano)-structured fluid with controlled release of barrier substances in said aquifer with the formation of an impermeable barrier located at the oil/water interface, characterized in that said fluid comprises an aqueous dispersion of microcapsules composed of a core comprising a modifying substance of the absolute permeability of the rock formation which contains said reservoir, a protective shell insoluble in water which coats said core. The present invention also relates to the above mentioned microcapsules and an aqueous dispersion comprising the above mentioned microcapsules to be used in said method. | 03-27-2014 |
| 20140083705 | MICROEMULSION TO IMPROVE THE FLOW OF HEAVY HYDROCARBONS, ITS PREPARATION AND USE - A microemulsion is formulated with a surfactant, a co-surfactant and brine, for recovery of heavy and extra-heavy crude oils by reducing the viscosity of such crude oils and improving their rheological properties for production and pipeline transportation. | 03-27-2014 |
| 20140083706 | Methods and Systems for Providing Steam - A steam system is provided that includes a steam generator including boiler tubes that are modified to form a number of intermediate take-offs for removing water and steam from the boiler tubes. A number of intermediate separators are provided to separate the water and steam at each of the intermediate take-offs. Intermediate couplings are used to inject the water back into the boiler tubes downstream of each of the plurality of intermediate take-offs. | 03-27-2014 |
| 20140090847 | Dehydrated Gel Compositions and Methods of Using the Same - Methods and compositions using gel compositions in treatment fluids employed in subterranean operations. A method includes providing a degradable gel precursor as a solid or dispersion in which substantially all the water has been removed, the degradable gel precursor being formed by a combination of a monomer and a degradable crosslinking agent of formula R | 04-03-2014 |
| 20140096967 | SALT-TOLERANT ANIONIC SURFACTANT COMPOSITIONS FOR ENHANCED OIL RECOVERY (EOR) APPLICATIONS - The present invention includes compositions and methods for using an anionic surfactant composition for treating a hydrocarbon-bearing formation or a reservoir, of formula (I): | 04-10-2014 |
| 20140102706 | METHOD AND APPARATUS FOR MIXING FLUID FLOW IN A WELLBORE USING A STATIC MIXER - Methods and apparatus are presented for mixing fluid flowing through a wellbore extending through a subterranean formation. A static mixer assembly is positioned in a tubing string, the mixer having a plurality of vanes extending radially into an interior fluid flow passageway. Downhole tools are movable through a tool passageway defined in the static mixer assembly. The tools can pass unobstructed by the fixed vanes. Alternately, the tool can flex the elastic vanes as it passes through, the vanes returning to position after passage of the tool. The vanes are preferably circumferentially spaced and longitudinally spaced. The vanes can extend from an interior wall surface of the assembly or from a sleeve inserted into the mixer assembly. | 04-17-2014 |
| 20140102707 | CROSSLINKED SWELLABLE POLYMER - The invention is directed to stable crosslinked water-soluble swellable polymers, methods for making same, and their various uses in the hygiene and medical arts, gel electrophoresis, packaging, agriculture, the cable industry, information technology, in the food industry, papermaking, use as flocculation aids, and the like. More particularly, the invention relates to a composition comprising expandable polymeric microparticles having labile crosslinkers and stable crosslinkers, said microparticle mixed with a fluid and an unreacted tertiary crosslinker that is capable of further crosslinking the microparticle on degradation of the labile crosslinker so as to form a stable gel. A particularly important use is as an injection fluid in petroleum production, where the expandable polymeric particles are injected into a well and when the heat and/or pH of the well cause degradation of the labile crosslinker and when the particle expands, the tertiary crosslinker crosslinks the polymer to form a stable gel, thus diverting water to lower permeability regions and improving oil recovery. | 04-17-2014 |
| 20140110118 | INCLUSION PROPAGATION BY CASING EXPANSION GIVING RISE TO FORMATION DILATION AND EXTENSION - The present invention is a method and apparatus for enhanced recovery of petroleum fluids from the subsurface by initiating and propagating vertical permeable inclusions in a plane substantially orthogonal to the borehole axis. These inclusions containing proppant are thus highly permeable and enhance drainage of heavy oil from the formation, and also by steam injection into these planes, enhance oil recovery by heating the oil sand formation, the heavy oil and bitumen, which will drain under gravity and be produced. Multiple propped vertical inclusions are constructed at various locations along a substantially horizontal wellbore by dilation of the formation in the plane of the intended inclusion by radial expansion and axial extension of the formation by an expanding packer system that expands both radially and axially. In another embodiment of the invention, the expansion device is part of a casing string or liner and is in contact with the formation by a swellable elastomer, or by a cement or polymer based grout. The expansion device is expanded by an inflatable packer and the device expands both radially outward and extensionally in the axial direction, giving rise to a dilated extensional plane in the formation which is substantially orthogonal to the well bore axis. Injected fluid propagates preferentially in this dilated and extensional plane within the formation. | 04-24-2014 |
| 20140110119 | WELLBORE FLUID USED WITH SWELLABLE ELEMENTS - A method for completing a wellbore may include introducing a wellbore fluid into a wellbore, the wellbore fluid having a base fluid; and a solid weighting agent having a d90 of less than 20 microns; where the method may also include contacting the wellbore fluid with a swellable element in the wellbore; and allowing swelling of the swellable element. | 04-24-2014 |
| 20140116705 | One Trip Packer Plug Debris Milling and Removal Method - A combination tool is delivered to compacted debris above a packer whose plug is to be removed. The shoe or mill is on the lower end of an outer bushing and the grapple or overshot is held within the bushing but away from the shoe so that the shoe can advance into the debris as reverse circulation takes the cuttings up through a mandrel to a debris removal tool. When the shoe lands on the packer the surface personnel can see it on the weight indicator. Weight is then set down to overcome a resisting force of a breakable member such as a shear pin or a spring or both so that the grapple advances to engage the packer plug. Advancing the mandrel relative to the bushing with the shoe at its lower end also releases a torque lug that previously allowed tandem rotation of the mandrel with the bushing. | 05-01-2014 |
| 20140116706 | ALTERING THE INTERFACE OF HYDROCARBON-COATED SURFACES - Methods and compositions are provided wherein microorganisms are used to alter the interface of hydrocarbons and hydrocarbon-coated surfaces to increase oil recovery, for improved bioremediation and/or pipeline maintenance. | 05-01-2014 |
| 20140131045 | Downhole Tool Positioning System And Method - Downhole tool positioning systems and methods are disclosed which employ buoyancy-mediated tool displacement wherein the density of the tool or string connected to it, and the treatment fluid are matched to facilitate hydraulic translation of the tool in a deviated borehole or lateral with or without a mechanical translation device. | 05-15-2014 |
| 20140131046 | Densifying Carbon Dioxide With a Dispersion of Carbon Dioxide-Philic Water Capsules - This invention generally relates to the field of oil recovery from reservoirs. More specifically, it relates to the recovery of oil from sandstone and carbonate reservoirs using a process for preparing a dispersion of capsules for use downhole including the steps of providing capsules containing a dense liquid, each capsule having a capsule wall defining an inner area, the capsule wall having an outer side. The capsules are functionalized by adding a carbon dioxide-philic compound compound to the outer side of the capsule wall. A dispersion is then prepared by adding the functionalized capsules to supercritical carbon dioxide such that a stable dispersion of capsules in supercritical carbon dioxide is achieved. | 05-15-2014 |
| 20140151049 | APPARATUS AND METHOD OF DELIVERING A FLUID USING DIRECT PROPPANT INJECTION - An apparatus and method for delivering a fluid mixture using direct injection to a mixing apparatus. The apparatus including a proppant storage vessel configured to contain therein a proppant material and output a proppant output flow at ambient pressure to a solid feed pump assembly. The apparatus further including a fracturing fluid storage vessel configured to contain therein a fracturing fluid and output a fracturing fluid output flow at a fracture fluid blending pressure. The solid feed pump assembly configured to output to a mixing apparatus, a proppant output flow at the fracture fluid blending pressure. The mixing apparatus configured to output a fluid mixture of the proppant and the fracturing fluid at the fracture fluid blending pressure. The mixing apparatus coupled to a high pressure pump assembly and configured to deliver the fluid mixture therein to a downstream component at an injection pressure. | 06-05-2014 |
| 20140151050 | Injection System for Enhanced Oil Recovery - A method of enhancing oil recovery by providing a mobile surfactant injection system including a storage tank, means for injecting surfactant into a scCO | 06-05-2014 |
| 20140158359 | Methods for Increasing Subterranean Formation Permeability - Methods for increasing the permeability of a portion of a subterranean formation surrounding a wellbore using non-hydrolyzed liquid esters to attack carbonates within acid-soluble formations without requiring the use of a catalyst or enzyme. Some methods comprise providing a treatment fluid comprising a non-hydrolyzed liquid ester in a base fluid; introducing the treatment fluid into a subterranean formation at matrix flow rates to allow the non-hydrolyzed liquid ester to penetrate into at least a portion of the subterranean formation; and leaving the treatment fluid in contact with the subterranean formation for a period of time during which at least a portion of the non-hydrolyzed liquid ester hydrolyzes to produce an acid. | 06-12-2014 |
| 20140158360 | DRAG REDUCING AGENTS FOR OIL- AND SYNTHETIC-BASED FLUIDS - Minimizing circulating pressure loss and/or reducing friction in drilling fluid operations to minimize equivalent circulating density (ECD) and maximize flow for borehole cleaning, tool optimization and efficient drilling may be achieved by the addition of friction improvers or drag reducers while circulating drilling fluids. Suitable drag reducers may include, but not necessarily be limited to, poly(alpha-olefins); polyisobutylene; condensation polymers of dicarboxylic acids or anhydrides, or polyols and monocarboxylic acids, addition polymers of unsaturated esters; copolymers of alpha-olefins with unsaturated esters; polystyrene acylated with long chain fatty acids; polyalkylene oxides; copolymers of alkyl acrylates with N-containing olefins; and combinations thereof. | 06-12-2014 |
| 20140166287 | POLYMER FORMULATIONS IN SOLVENTS WITH A HIGH FLASHPOINT, PROCESSES FOR PRODUCTION THEREOF AND USE THEREOF AS POUR POINT DEPRESSANTS FOR CRUDE OILS, MINERAL OILS OR MINERAL OIL PRODUCTS - Polymer formulations comprising at least two different solvents having a flashpoint ≧60° C., and polymeric compositions obtainable by free-radical polymerization of at least one alkyl (meth)acrylate in the presence of at least one ethylene-vinyl ester copolymer. Multistage process for producing such formulations and the use of such formulations as pour point depressants for crude oils, mineral oils or mineral oil products. | 06-19-2014 |
| 20140166288 | SQUEEZE TREATMENT FOR IN SITU SCAVENGING OF HYDROGEN SULFIDE - A method of performing a squeeze treatment comprises pumping a treatment fluid under pressure through a wellbore into a subterranean formation, wherein the treatment fluid includes a hydrogen sulfide scavenging compound that adsorbs onto the subterranean formation in a region around the wellbore. Production fluids are then allowed to flow from the subterranean formation into the wellbore, wherein the production fluids contact the adsorbed hydrogen sulfide scavenging compound as the production fluids flow through the region around the wellbore, and wherein the production fluids contain hydrogen sulfide that reacts with the hydrogen sulfide scavenging compound to reduce an amount of hydrogen sulfide in the production fluids before the production fluids flow into the wellbore. | 06-19-2014 |
| 20140166289 | SCAVENGING HYDROGEN SULFIDE - Alpha-hydroxy alkyl esters have been found to perform as hydrogen sulfide scavengers. A method of scavenging hydrogen sulfide includes contacting a fluid containing hydrogen sulfide with a treatment fluid including an alpha-hydroxy alkyl ester. Accordingly, the alpha-hydroxy alkyl ester reacts with the hydrogen sulfide to reduce the amount of hydrogen sulfide in the fluid. A broad range of alpha-hydroxy alkyl esters are disclosed. | 06-19-2014 |
| 20140166290 | Method for Individually Servicing a Plurality of Zones of a Subterranean Formation - A method of servicing a subterranean formation comprising providing a first sleeve system comprising a first one or more ports and being transitionable from a first mode to a second mode and from the second mode to a third mode, and a second sleeve system comprising a second one or more ports and being transitionable from a first mode to a second mode and from the second mode to a third mode, wherein, in the first mode and the second mode, fluid communication via the one or more ports of the first or second sleeve system is restricted, and wherein, in the third mode, fluid may be communicated via the one or more ports of the first or second sleeve system, transitioning the first and second sleeve systems to the second mode, and allowing the first sleeve system to transition from the second mode to the third mode. | 06-19-2014 |
| 20140174745 | Treated Geothermal Brine Compositions With Reduced Concentrations of Silica, Iron, and Zinc - This invention relates to treated geothermal brine compositions containing reduced concentrations of iron, silica, and zinc compared to the untreated brines. Exemplary compositions contain concentration of zinc ranges from 0 to 300 mg/kg, concentration of silica ranges from 0 to 30 mg/kg, concentration of iron ranges from 0 to 300 mg/kg. Exemplary compositions also contain reduced concentrations of elements like lithium, manganese, arsenic, barium, and lead. Exemplary compositions include Salton Sea brines containing a concentration of zinc less than 10 mg/kg, a concentration of silica ranging from less than 10 mg/kg, and a concentration of iron less than 10 mg/kg. | 06-26-2014 |
| 20140182854 | FLUID LOSS CONTROL PILL WITH INTERNAL BREAKER AND METHOD - A method of treating a subterranean formation. The method may include providing a fluid loss control pill that comprises an aqueous base fluid, a gelling agent, and an internal breaker that is selected from the group consisting of inorganic delayed acids or inorganic salts. The method can include introducing the fluid loss control pill into a subterranean formation, allowing the internal breaker to reduce the viscosity of the pill after a delay period, and allowing the fluid loss control pill to break. | 07-03-2014 |
| 20140182855 | INJECTION DEVICE - An injection device for use in injecting a fluid into a target location comprises a housing and a valve assembly located within the housing. The housing defines an inlet for communicating with an injection line, an outlet for communicating with a target location, and an injection fluid flow path extending between the inlet and outlet. The valve assembly located is configured to control the flow of injection fluid along the flow path and comprises first and second valve members both arranged to move within the housing, wherein in an open configuration to permit flow the first and second members are disengaged, and in a closed configuration to prevent flow the first and second members are engaged and the first valve member is biased against the second member by inlet fluid pressure to assist sealing therebetween. | 07-03-2014 |
| 20140190699 | Recovery of Oil - A treatment formulation for use in enhanced oil recovery is described which includes a dispersing polymer which may be a partly hydrolyzed polyvinyl alcohol and a displacing polymer which may be a partially hydrolysed polyacrylamide. | 07-10-2014 |
| 20140196904 | Methods of Controlled Release pH Adjustment for Oilwell Stimulation - A method for treating subterranean formations by the use of delayed release pH control agents in subterranean formations during fracturing operations includes providing a fracturing fluid comprising a base fluid, a viscosifying agent, a pH sensitive crosslinking agent, and a delayed release pH-adjusting material. The delayed release pH-adjusting material includes a pH-adjusting agent and a binder. The fracturing fluid is introduced into a subterranean formation, and the pH of the fracturing fluid is changed through at least partial degradation or disassociation of the delayed release pH-adjusting material, thereby allowing the viscosifying agent to be crosslinked through activation of the pH sensitive crosslinking agent. | 07-17-2014 |
| 20140216748 | BIFUNCTIONAL ANTI-DEPOSIT AND ANTI-CORROSION ADDITIVES - The invention concerns bifunctional compositions usable in the field of extraction of hydrocarbons, oil and/or gas, said compositions being homogeneous, clear and stable and comprising at least one anti-mineral-deposit additive, at least one corrosion inhibitor, and at least one agent for compatibilizing between the anti-mineral-deposit additive and the corrosion inhibitor. | 08-07-2014 |
| 20140238682 | METHOD AND APPARATUS FOR WELLBORE FLUID TREATMENT - A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in in a pressure tight condition and later is needed to be in an open-port condition. | 08-28-2014 |
| 20140246197 | COMPACT WELLHEAD SYSTEM WITH BUILT-IN PRODUCTION CAPABILITY - A production system for producing hydrocarbons from a subterranean reservoir includes a wellhead including a housing and a head. The housing has a central axis, an upper end, a lower end, and an inner surface. The inner surface defines a passage extending axially through the housing. In addition, the inner surface of the housing includes an annular recess positioned between the upper end and the lower end. The housing also includes a first production port extending radially through the housing. Further, the system includes a casing hanger disposed within the housing. The casing hanger has an upper end, a lower end, an outer surface, and a through bore extending from the upper end to the lower end. The casing hanger also includes a plurality of circumferentially-spaced ports extending radially through the casing hanger from the through bore to the annular recess of the housing. | 09-04-2014 |
| 20140246198 | BRANCHED VISCOELASTIC SURFACTANT FOR HIGH-TEMPERATURE ACIDIZING - A treatment fluid for use in a subterranean formation penetrated by the wellbore of a well includes: (i) water; (ii) a strong acid; and (iii) a branched viscoelastic surfactant having a hydrophobic portion with a total of 16 to 20 carbons; wherein the pH of the treatment fluid is less than 0.5; and wherein the viscosity of the treatment fluid is less than 5 cP at 40 sec-1. A method of treating a zone of a subterranean formation penetrated by a wellbore includes the steps of forming the treatment; (B) introducing the treatment fluid through the wellbore into the zone; and (C) allowing time for the strong acid in the treatment fluid to spend in the formation. Such a treatment fluid shows good rheological properties at temperatures above 93° C. (200° F.). | 09-04-2014 |
| 20140251618 | METHOD TO IMPROVE CONFORMANCE CONTROL IN CARBON DIOXIDE FLOODING - This invention generally relates to the field of oil recovery from reservoirs. More specifically, it relates to enhancing the recovery of oil using carbon dioxide flooding processes. In general, the invention provides a process to improve oil recovery from a reservoir by injecting through a well into a reservoir a heavy oil slug composition that includes heavy oil that is mixed carbon dioxide. Following injecting the heavy oil slug composition, a carbon dioxide slug that includes carbon dioxide is injected through the well into the reservoir. | 09-11-2014 |
| 20140251619 | Method and Apparatus for Establishing Injection into a Cased Bore Hole using a Time Delay Toe Injection Apparatus - An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation, providing a time delay before fluid is passed through the ports, allowing multiple valves to be used in the same well casing and providing a focused jetting action to better penetrate a concrete casing lining. | 09-11-2014 |
| 20140251620 | Method and Apparatus for Establishing Injection into a Cased Bore Hole using a Time Delay Toe Injection Apparatus - An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention is a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation, providing a time delay before fluid is passed through the ports. This time delay allows multiple valves to be used in the same well casing and providing a focused jetting action to better penetrate a concrete casing lining. | 09-11-2014 |
| 20140251621 | THROUGH TUBING PERPENDICULAR BORING - Methods for extracting more fluids from oil and gas wells reservoirs than is currently possible using the current art of drilling and hydraulic fracturing wells may be accomplished with methods and apparatuses to directionally control the construction of a plurality of substantially perpendicular boreholes from a common wellbore at a plurality of positions along said common wellbore. One method may include drilling a plurality of the substantially perpendicular boreholes off a previously constructed common wellbore using underbalanced methods and producing the reservoir fluids while drilling the substantially perpendicular boreholes. In some methods, injection of fluids from surface into subterranean reservoirs may be used for the purpose of sequestering fluids or recovering fluids to the surface. | 09-11-2014 |
| 20140262281 | Methods of Designing a Drilling Fluid Having Suspendable Loss Circulation Material - Methods including providing a wellbore in a subterranean formation having at least one pore opening; providing a proposed wellbore operation; providing a proposed treatment fluid; providing proposed FLCM particulates; calculating the suspendability of the proposed FLCM particulates in the proposed treatment fluid as determined by a yield gravity function based on properties of the proposed treatment fluid and properties of the proposed FLCM particulates or as determined by an experimental FLCM function; manipulating at least one of the properties of the proposed treatment fluid, the properties of the proposed FLCM particulates, or the proposed wellbore operation based on the yield gravity function or the experimental FLCM function so as to produce a FLCM-suspension treatment fluid; and introducing the FLCM-suspension treatment fluid into the wellbore in the subterranean formation so as to contact the at least one pore opening. | 09-18-2014 |
| 20140262282 | MIXED CARBON LENGTH SYNTHESIS OF PRIMARY GUERBET ALCOHOLS - In an embodiment of the disclosure, mixtures of different carbon length alcohols are used as the primary feedstock for Guerbet alcohols. Specifically, embodiments relate to a method of synthesizing mixed molecular weight surfactants from a mixture of primary alcohols comprising, receiving a mixture of primary alcohols comprising at least two different chain length primary alcohols and reacting the mixture of primary alcohols to produce a mixture of Guerbet alcohols. The mixture of Guerbet alcohols is then used to produce a surfactant composition comprising surfactants of different molecular weights. | 09-18-2014 |
| 20140262283 | METHODS FOR TREATMENT OF A SUBTERRANEAN FORMATION - The present invention relates to methods of treating subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation including placing a first aqueous composition and a second aqueous composition in a subterranean formation. The placing includes injecting the first aqueous composition through a tubular passage in a wellbore. The placing also includes injecting the second aqueous composition through an annular passage in the wellbore. | 09-18-2014 |
| 20140262284 | METHOD OF FORMING AND COMPRESSING CARBON DIOXIDE - A method and apparatus to form and compress relatively pure carbon dioxide includes a syngas generator which forms syngas and directs it into a combustion chamber where it is combined with oxygen and combusted to form relatively pure carbon dioxide. A first portion of the formed carbon dioxide is directed to a compressor which is powered by an internal combustion engine. A second portion of the formed carbon dioxide is combined with oxygen and used in combination with a carbonaceous fuel to power the internal combustion engine. This produces exhaust gas which is relatively high purity carbon dioxide which is combined with the carbon dioxide formed by combusting the syngas. | 09-18-2014 |
| 20140262285 | METHODS FOR FRACCING OIL AND GAS WELLS - A method for stimulating or fraccing an oil or a natural gas well by adding a liquefied hydrocarbon such as liquid petroleum gas and liquefied natural gas, a proppant and a diluent such as carbon dioxide, nitrogen or mixtures thereof to the well. The order of addition is typically liquefied hydrocarbon then diluent but this order can be reversed and in other circumstances the liquefied hydrocarbon and diluent can be mixed together and fed to the well as a mixture. | 09-18-2014 |
| 20140262286 | COMPOSITION AND METHOD FOR REMEDIATION OF NEAR WELLBORE DAMAGE - Aspects of the invention relate to compositions and methods that are used for remediation of near-wellbore damage. A specific aspect is a composition comprising an olefin sulfonate, a sulfosuccinate, and a chemical selected from the group consisting of an alcohol alkoxylated sulfate, an alcohol alkoxylated carboxylate, or a combination thereof. | 09-18-2014 |
| 20140262287 | ENVIRONMENTALLY FRIENDLY QUATERNARY SALTS OF AMINES AND THEIR USE AS TEMPORARY AND/OR PERMANENT CLAY STABILIZERS AND METHODS FOR MAKING AND USING SAME - New classes of temporary and/or permanent clay stabilization compositions including at least one quaternary salt of primary amines, secondary amines, tertiary amines, reaction products of these amines with at least one aldehyde, or mixtures and combinations thereof and to methods for making and using same, where the quaternary salts have reduced toxicity. | 09-18-2014 |
| 20140284056 | N-ACYL AMINO ACID ALKYLAMIDE IN OIL-BASED PARTICULATE CARRIER FLUIDS FOR WELL TREATMENTS - A well fluid including: (i) an oleaginous continuous phase; (ii) an N-acyl amino acid alkylamide; and (iii) a solid particulate. A method of treating a portion of a well with a particulate, the method including the steps of: (A) forming the well fluid; and (B) introducing the well fluid into the well. In addition, the N-acyl amino acid alkylamide affords an invert emulsion with a high OWR ratio, that is, greater than 40% oil by volume, for example, 70:30. The invert emulsion has a low viscosity, but can still suspend gravel. In a gravel packing application, the low viscosity of the invert emulsion fluid eliminates the need to break the emulsion during flow-back. | 09-25-2014 |
| 20140284057 | METHODS AND COMPOSITIONS FOR USE IN OIL AND/OR GAS WELLS - 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. | 09-25-2014 |
| 20140290953 | METHOD AND COMPOSITION FOR ENHANCED HYDROCARBONS RECOVERY FROM A FORMATION CONTAINING A CRUDE OIL - A hydrocarbon recovery composition comprising vinylidene olefin sulfonates is described. A method of treating a crude oil formation and a method of preparing the hydrocarbon recovery composition are also described. | 10-02-2014 |
| 20140290954 | Wellbore Strengthening Composition - In one aspect, embodiments disclosed herein relate to a wellbore strengthening composition including at least one polymer capable of polymerizing through a free radical polymerization reaction from the group of epoxy acrylates, modified epoxy acrylates, epoxy precursors, modified epoxy vinyl esters, unsaturated polyesters, urethane(meth)acrylates, polyester acrylates, epoxy vinyl ester resins having the wherein R and R | 10-02-2014 |
| 20140290955 | METHOD - The invention provides a method for increasing the retention of a scale inhibitor within a hydrocarbon producing system, including the steps of: (i) pre-flushing said system with a liquid; (ii) treating said system with a scale inhibitor; and (iii) over-flushing said system with a composition comprising an ionic polymer and a liquid carrier, wherein the concentration of said ionic polymer in said composition is 5 to 50% wt. | 10-02-2014 |
| 20140299325 | COMPOSITIONS AND METHODS FOR ENHANCEMENT OF PRODUCTION OF LIQUID AND GASEOUS HYDROCARBONS - A well treatment composition is well-designed for the simultaneous enhancement of the production of both liquid and gaseous hydrocarbons from the same reservoir on a non-selective basis. The well treatment composition includes a first surfactant and a second surfactant, wherein the second surfactant is selected from the group consisting of ethoxylated alkylene amines, ethoxylated alkyl amines, propoxylated alkylene amines, propoxylated alkyl amines, ethoxylated-propoxylated alkylene amines and ethoxylated-propoxylated alkyl amines. The well treatment composition also includes a first solvent, a second solvent and water. Methods for using the well treatment composition include the steps of emplacing the well treatment composition into wells having high and low gas-to-oil ratios. | 10-09-2014 |
| 20140305646 | COMPOSITION OF POLYBUTADIENE-BASED FORMULA FOR DOWNHOLE APPLICATIONS - A method of treating a wellbore may include emplacing in at least a selected region of the wellbore a formulation that includes at least one diene pre-polymer; at least one reactive diluent; at least one inert diluent comprising an oleaginous liquid or a mutual solvent; and at least one initiator; and initiating polymerization of the at least one diene pre-polymer and the at least one reactive diluent to form a composite material in the selected region of the wellbore. | 10-16-2014 |
| 20140305647 | METHODS OF PRODUCING FRICTION REDUCING BIOSYNTHETIC POLYSACCHARIDES - Methods of treating a subterranean formation including providing a treatment fluid comprising an aqueous base fluid and a friction reducing agent, wherein the friction reducing agent is a biosynthetic polysaccharide produced by a host cell line with DNA encoding the biosynthetic polysaccharide; and introducing the treatment fluid into the subterranean formation. | 10-16-2014 |
| 20140318792 | SYSTEM AND METHOD FOR ENHANCED RECOVERY OF OIL FROM AN OIL FIELD - An oil recovery system and method is disclosed. The system includes a solar power tower for receiving a first portion of water from a water treatment device. The solar power tower heats the first portion of water directly using solar radiation and generates a first steam. Further, the system includes a boiler for receiving a second portion of water from the water treatment device. The boiler heats the second portion of water and generates a second steam. Further, the system includes a flow control device coupled to the solar power tower and the boiler to receive at least one of the first steam and the second steam. The flow control device injects at least one of the first steam and the second steam to an oil field. | 10-30-2014 |
| 20140318793 | HYDRAULIC DIVERSION SYSTEMS TO ENHANCE MATRIX TREATMENTS AND METHODS FOR USING SAME - Systems and methods for treating formation intervals including forming a low permeability layer on a surface of the interval and pumping a sand control treating solution through the layer, which diverts the flow into the formation permitting improved treatment uniformity and improved overall internal treatment. | 10-30-2014 |
| 20140326457 | Process For The Enhanced Recovery Of Oil By Injection Of A Polymer Solution - Process for the enhanced recovery of oil comprising introducing into the injection fluid at least one linear or structured water-soluble copolymer obtained by polymerization of:
| 11-06-2014 |
| 20140326458 | PROCESS FOR THE ENHANCED RECOVERY OF OIL BY INJECTION OF A POLYMER SOLUTION - Process for enhanced oil recovery employing an aqueous solution comprising at least one linear or structured water-soluble copolymer obtained by polymerization:
| 11-06-2014 |
| 20140338912 | THERMALLY-ACTIVATED GELLANT FOR AN OIL OR GAS TREATMENTFLUID - A treatment fluid for treating a portion of a subterranean formation comprises: a base fluid, wherein the base fluid comprises a hydrocarbon liquid; and a gellant, wherein the gellant: is a polymer; and is activated at an activation temperature, wherein the thermal activation of the gellant causes the treatment fluid to become a gel. A method of treating a portion of a subterranean formation includes introducing the treatment fluid into the portion of the subterranean formation, wherein the subterranean formation is penetrated by a well, wherein at least a portion of the well has a bottomhole temperature greater than or equal to the activation temperature, and wherein the step of introducing comprises introducing the treatment fluid into the portion of the well. | 11-20-2014 |
| 20140338913 | TREATMENT FLUID CONTAINING A CORROSION INHIBITOR OF A WEAK BASE - A treatment fluid comprising: water; a formate; and a corrosion inhibitor, wherein the corrosion inhibitor is capable of providing: (A) a pH of at least 10; and (B) a corrosion rate equal to or less than 4 mils per year wherein carbon dioxide accounts for at least 100 psi (0.7 MPa) of the total pressure, for a test fluid consisting essentially of: the water; the formate; and the corrosion inhibitor, and in the same proportions as in the treatment fluid, whereas a substantially identical test fluid without the corrosion inhibitor has a pH of less than 10 and a corrosion rate of greater than 4 mils per year under the testing conditions. The treatment fluid can further comprise a scale inhibitor. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well. | 11-20-2014 |
| 20140345868 | METHOD OF MAINTAINING OIL RESERVOIR PRESSURE - The method of maintaining oil reservoir pressure involves injecting seawater having a concentration of about 1 wt % of a polyamino carboxylic acid or salt thereof as a chelating agent into the water zone of an oil reservoir, which reduces the formation of scale, thereby maintaining oil reservoir pressure. The polyamino carboxylic acid may be ethylenediaminetetraacetic acid (EDTA), acid (HEDTA), or hydroxyethyliminodiacetic acid (HEIDA). When used in larger concentrations, e.g., between 5 to 10 wt %, flooding the core with seawater containing the polyamino carboxylic acids not only prevents scale formation, but also improves core permeability. Instead of seawater, low salinity water may be used for the latter purpose. | 11-27-2014 |
| 20140352966 | Method for Fast and Uniform SAGD Start-Up Enhancement - A method is taught for creating a laterally-continuous, vertically-oriented dilation zone connecting the two SAGD wells. The method comprises the steps of drilling and completing the SAGD wells in a formation, conditioning said wells to create a stress condition favorable for forming a dilation zone, injecting one or both of said two wells with a stimulant at pressures greater than the in-situ minimum stress of the formation to initiate the dilation zone connecting said SAGD wells and continuing stimulant injection into a first of said two wells while maintaining a target pressure at a second of said two wells to propagate the dilation zone homogenously along the well length. | 12-04-2014 |
| 20140352967 | MULTI-COMPONENT AQUEOUS GEL SOLUTION FOR CONTROL OF DELAYED GELATION TIMING AND FOR RESULTING GEL PROPERTIES - A method of using a water based solution having a controllable gel time. The method includes providing a predetermined ratio of a water soluble silicate solution having at least one alkali metal, providing a predetermined ratio of a water dispersible polymer, and providing a predetermined ratio of a water soluble initiator containing a reactive carbonyl compound. One embodiment of the method also includes combining the water soluble silicate solution, the dispersible polymer, and the water soluble initiator and injecting downhole in a single stage treatment. Another embodiment of the method includes pre-mixing at least the water soluble silicate solution and the dispersible polymer into a mixture, then injecting the water soluble initiator and the mixture downhole separately for a multi-stage treatment with in situ mixing. | 12-04-2014 |
| 20140360728 | DEGRADABLE COMPOSITE MATERIALS AND USES - In general, the current application relates to degradable composite and blend materials that have accelerated degradation in water in low temperature conditions, and their various industrial, medical and consumer product uses. In some embodiments, the degradable composite composition comprises a degradable polymer mixed with discrete particles of a filler that acts to accelerate the degradation of the degradable polymer. Such materials degrade in 60 C water in less than 30 days, <14 days, and even <7 days. Various materials are provided that can degrade equally fast at lower temperatures, such as 50 C, or even 40 C. | 12-11-2014 |
| 20140367107 | METHODS AND COMPOSITIONS FOR STIMULATING THE PRODUCTION OF HYDROCARBONS FROM SUBTERRANEAN FORMATIONS - 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 solvent, and a surfactant. In some embodiments, methods of selecting a composition for treating an oil or gas well are provided. | 12-18-2014 |
| 20140374103 | TREATING AND RECYLCING OILFIELD WASTE WATER - A process for treating oilfield waste water includes combining oilfield waste water and a biocide comprising hydrogen peroxide, the biocide being present in an amount effective to decrease a number density of bacteria in the oilfield waste water. A process for treating oilfield waste water includes measuring an oxidation reduction potential (ORP) of oilfield waste water; combining the oilfield waste water and an oxidizer in an amount to adjust the ORP of the oilfield waste water to be greater than or equal to a first ORP value; and adding a biocide comprising hydrogen peroxide to the oilfield waste water to adjust the ORP of the oilfield waste water to be greater than or equal to a second ORP value, to treat the oilfield waste water, the second ORP value being greater than the first ORP value. A process for recycling oilfield waste water includes combining oilfield waste water and a biocide comprising hydrogen peroxide; decreasing a number density of bacteria in the oilfield waste water to form treated water; introducing an additive to the treated water; and disposing the treated water in a subterranean environment. | 12-25-2014 |
| 20140374104 | COMPOSITION AND METHOD FOR TREATING OILFIELD WATER - A method for reducing sulfide in oilfield waste water includes contacting oilfield waste water with an oxidizer in the presence of an iron catalyst. The oilfield waste water includes sulfide that is oxidized to sulfate while avoiding formation of a colloidal or bulk sulfur precipitate. A method for recycling oilfield waste water includes contacting oilfield waste water with an oxidizer in the presence of an iron catalyst, the oilfield waste water comprising sulfide; oxidizing the sulfide to sulfate; avoiding formation of a colloidal sulfur precipitate, a bulk sulfur precipitate, or a combination comprising at least one of the foregoing; clarifying the oilfield waste water by contacting the oilfield waste water with a flocculant to form an aggregate precipitate; separating the aggregate precipitate from the oilfield waste water to form a recycled water; combining an additive with the recycled water; and disposing the recycled water in a downhole environment. | 12-25-2014 |
| 20140374105 | PROCESS FOR THE REMOVAL OF CARBON DIOXIDE FROM A GAS - Process for the removal of CO | 12-25-2014 |
| 20140374106 | MULTICOMPONENT DEGRADABLE MATERIALS AND USE - In general, the current disclosure relates to multicomponent fibers that have accelerated degradation in water in low temperature conditions, and their various industrial, medical and consumer product uses. Such materials are especially useful for uses in subterranean wells in oil and gas production. In some embodiments, the compositions of materials have accelerated degradation even at Ultra Low Temperature (“ULT”) (≦60° C.) in subterranean formations. | 12-25-2014 |
| 20150007995 | LUBRICATING COMPOSITIONS FOR USE WITH DOWNHOLE FLUIDS - An aqueous-based downhole fluid having a lubricant therein may be circulated within a subterranean reservoir wellbore where the downhole fluid may be or include a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof. The lubricant may include a clay stabilizer and a vegetable oil derivative, such as but not limited to, a sulfonated vegetable oil. The downhole fluid may include the lubricant in an effective amount for lubricating a first surface. | 01-08-2015 |
| 20150013987 | METHOD FOR REDUCING SULFIDE IN OILFIELD WASTE WATER AND MAKING TREATED WATER - A process for treating oilfield waste water includes contacting the oilfield waste water with hydrogen peroxide, the oilfield waste water comprising sulfide; oxidizing the sulfide to sulfur; and precipitating the sulfur to form treated water from the oilfield waste water. A process for recycling oilfield waste water includes combining the oilfield waste water and hydrogen peroxide, the oilfield waste water comprising sulfide; oxidizing the sulfide to sulfur; forming a precipitate comprising a colloidal sulfur precipitate, a bulk sulfur precipitate, or a combination comprising at least one of the foregoing; removing the precipitate from the oilfield waste water to form treated water; introducing an additive to the treated water; and disposing the treated water in a subterranean environment. | 01-15-2015 |
| 20150027712 | APPARATUS AND METHODS FOR DELIVERING A HIGH VOLUME OF FLUID INTO AN UNDERGROUND WELL BORE FROM A MOBILE PUMPING UNIT - Apparatus for pumping fluid into an underground well bore at a well site and being transportable between multiple well sites includes a chassis configured to be transportable between well sites, first and second fluid pumps disposed upon the chassis and configured to pump pressurized fluid into the well bore at the same time and an electric motor disposed upon the chassis and configured to concurrently drive both pumps. | 01-29-2015 |
| 20150034322 | STEAM GENERATION WITH CARBON DIOXIDE RECYCLE - Systems and methods relate to recovering hydrocarbons by injecting into a reservoir steam along with carbon dioxide recovered from flue gases produced while generating the steam and from separation of produced fluids. Due to benefits from the carbon dioxide injection, carbon dioxide capture rates from the flue gases selected below fifty percent in such combined recovery of the carbon dioxide enables lower fuel consumption even given that additional fuel is needed for the carbon dioxide capture versus steam only operations. As the capture rates from the flue gases increase above fifty percent like when employed for sequestration purposes, such approaches use more fuel than the steam only operations and may not be cost efficient. A carbon dioxide recovery unit coupled to an air-fired boiler or an auxiliary oxy-fired boiler may supply the carbon dioxide recovered from the flue gases. | 02-05-2015 |
| 20150034323 | SAND CONTROL SYSTEM AND METHODOLOGY - A technique facilitates a more desirable inflow distribution of fluid along a tubing string deployed in a wellbore. The technique comprises providing a tubing string with a plurality of flow control devices and conveying the tubing string downhole into the wellbore. An injection fluid is pumped down along an interior of the tubing string and out through the plurality of flow control devices for entry into the surrounding formation. Based on a function of this injection flow, the flow areas of the flow control devices are adjusted to improve the subsequent distribution of inflowing fluids. The injection and the subsequent adjustment of flow areas as a function of the injection flow through each flow control device may be repeated for continued improvement, e.g. continued optimization, of the inflow distribution. | 02-05-2015 |
| 20150047848 | METHOD OF REDUCING DUST WITH PARTICULATES COATED WITH A POLYCATIONIC POLYMER - A well treatment composite is characterized by particulates wherein at least a portion of the substrate of the particulates is coated with a polycationic polymer. The presence of the polycationic polymer on the surface of the well treatment particulates reduces the generation of dust and fines during a well treatment operation. The polycationic polymer further reduces the amount of dust or fines generated during transport of the well treatment particulates to a remote location as well during the manufacture or processing of well treatment particulates. | 02-19-2015 |
| 20150060074 | Methods and Fluid Compositions for Creating a Wellbore - An operations fluid composition for operations on wells associated with the production of hydrocarbons, the fluid composition comprising: not less than 40 wt % of hydrocarbon fluid, based upon the total weight of the fluid composition; water; and from 0.1 to 10 wt % of a surfactant selected from alkyl acid surfactant, based upon the total weight of water in the fluid composition. Method for using the same are also disclosed. | 03-05-2015 |
| 20150068751 | SILOXANE SURFACTANT ADDITIVES FOR OIL AND GAS APPLICATIONS - A well treatment additive includes a siloxane surfactant, a solvent and an aqueous phase. The solvent, in some embodiments, is a terpene hydrocarbon. Also disclosed is a method for using the well treatment additive to form and enhance the properties of foams useful for the treatment of oil and gas wells. Methods of using the novel well treatment foams include using the additives in a variety of well treatment processes including, but not limited to, acidizing operations, hydraulic fracturing operations, well remediation operations and water removal operations. | 03-12-2015 |
| 20150075795 | Well Treatment Methods and Fluids Containing Synthetic Polymer - A well treatment fluid uses ingredients that include an aqueous base, a non-associative, ionic, synthetic polymer, and optionally, at least one metal crosslinker. The polymer contains a backbone and a functional group that hinders hydrolysis of the backbone. The functional group is distributed at intervals on the backbone. A well treatment method includes forming a well treatment fluid by combining ingredients including a non-associative, ionic, synthetic polymer and a first aqueous base. The first fluid exhibits a first viscosity greater than a viscosity of the first aqueous base. The method includes treating a well during a stage using the first fluid exhibiting the first viscosity. A second well treatment fluid is formed by combining ingredients including the polymer, a second aqueous base, and at least one crosslinker and by crosslinking the synthetic polymer. The method includes treating the well during another stage using the second fluid exhibiting the second viscosity. | 03-19-2015 |
| 20150075796 | WELLSITE HANDLING SYSTEM FOR PACKAGED WELLSITE MATERIALS AND METHOD OF USING SAME - Systems and methods for handling wellsite packets for a wellsite are provided. The wellsite packets include soluble packaging with wellsite materials therein. The wellsite has surface equipment and downhole equipment positioned about a wellbore. The handling system includes at least one feeder, at least one mixer, at least one metering device, and a pump. The feeder moves the wellsite packets directly or indirectly into the mixer. The mixer stimulates dissolution of the soluble packaging so as to mix the wellsite materials with a fluid to form a wellsite mixture. The metering device selectively controls the number of wellsite packets moving to the mixer. The pump is operatively coupled to the mixer to pump the wellsite mixture at the wellsite. | 03-19-2015 |
| 20150083425 | INLINE NON-TARGETED COMPONENT REMOVAL - An improved method for the removal of non-targeted components from a non-targeted component containing gas stream, the method includes the steps of: (i) contacting the non-targeted component containing gas stream with a fluid solvent stream; (ii) passing the product of step i) through a co-current phase separation step to produce both a non-targeted component containing solvent stream and a partially purified gas stream; (iii) passing the partially purified gas stream product of step ii) through a mass transfer step to produce a wet gas product; and (iv) passing the wet gas product of step iii) through a final co-current phase separation step to produce a purified gas stream, wherein the method is performed in a subsea location. | 03-26-2015 |
| 20150090456 | FLUORESCENT NANO-SENSORS FOR OIL AND GAS RESERVOIR CHARACTERIZATION - 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. | 04-02-2015 |
| 20150096755 | COMPOSITIONS COMPRISING CARBON DIOXIDE AND REVERSE MICELLES AND METHODS OF USE - Provided herein is a composition comprising carbon dioxide, an aqueous phase, and reverse micelles, wherein the reverse micelles comprise a metal cation-chelating agent, and a metal cation; and methods of using said composition for sequestering carbon dioxide and/or recovering hydrocarbons from a hydrocarbon reservoir. | 04-09-2015 |
| 20150101816 | CHEMICAL AMENDMENTS FOR THE STIMULATION OF BIOGENIC GAS GENERATION IN DEPOSITS OF CARBONACEOUS MATERIAL - Methods of stimulating biogenic production of a metabolic product with enhanced hydrogen content are described. The methods may include accessing a consortium of microorganisms in a geologic formation that includes a carbonaceous material. They may also include providing hydrogen and one or more phosphorous compounds to the microorganisms. The combination of the hydrogen and phosphorous compounds stimulates the consortium to metabolize the carbonaceous material into the metabolic product with enhanced hydrogen content. Also, methods of stimulating biogenic production of a metabolic product with enhanced hydrogen content by providing a carboxylate compound, such as acetate, to a consortium of microorganisms is described. The carboxylate compound stimulates the consortium to metabolize carbonaceous material in the formation into the metabolic product with enhanced hydrogen content. | 04-16-2015 |
| 20150107840 | PROCESS FOR RECOVERY OF OIL FROM AN OIL-BEARING FORMATION - The present invention is directed to a process for producing oil. The mass action ratio (MAR) of divalent cations to monovalent cations of water from an oil-bearing formation is determined, and an aqueous displacement fluid having a total dissolved solids content of from 200 ppm to 5,000 ppm and a MAR of divalent cations to monovalent cations of from 70% to 130% of the MAR of divalent cations to monovalent cations of the formation water is introduced into the formation. Oil is produced from the formation after introducing the aqueous displacement fluid into the formation. | 04-23-2015 |
| 20150107841 | PROCESS FOR REDUCING VISCOSITY OF POLYMER-CONTAINING FLUID PRODUCED IN THE RECOVERY OF OIL - The present invention is directed to a process for producing a fluid containing oil and water from an oil-bearing formation and separating an oil phase and an aqueous phase from the produced fluid. An aqueous polymer mixture is formed by mixing polymer in water having a total dissolved solids content of from 200 ppm to 15,000 ppm. The aqueous polymer mixture is injected into an oil-bearing formation, and, after injecting the aqueous polymer mixture into the formation, a fluid is produced from the oil-bearing formation containing an oil phase and an aqueous polymer-containing phase. Brine is mixed with the produced fluid to enhance separation of the oil phase from the aqueous polymer phase. | 04-23-2015 |
| 20150114647 | AQUEOUS SOLUTION AND METHOD FOR USE THEREOF - Aqueous compositions contain hydrochloric acid at a concentration between 8 wt % and 28 wt % inclusive. The amino acid; hydrochloric acid mole ratio may be between 0.2 and 1.5. Sufficient water is present to dissolve the hydrochloric acid and the amino acid. Such compositions have utility as retarders for acid compositions employed in the stimulation of subterranean formations. Slowing the reaction between the acid and formation helps maximize formation permeability and productivity. | 04-30-2015 |
| 20150114648 | PARYLENE COATED CHEMICAL ENTITIES FOR DOWNHOLE TREATMENT APPLICATIONS - Fluids including a parylene-coated chemical entity and methods of treating a subterranean formation with such fluids are disclosed. The methods may include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a parylene-coated particle having a chemical entity encapsulated therein. | 04-30-2015 |
| 20150114649 | SEALANT COMPOSITIONS FOR USE IN SUBTERRANEAN FORMATION OPERATIONS - Methods comprising providing a sealant composition comprising an aqueous base fluid and a crosslinkable polymer composition, wherein the crosslinkable polymer composition comprises a crosslinkable organic polymer and a crosslinker; introducing an elastic gellable composition into the sealant composition, wherein the elastic gellable composition is an aqueous emulsion comprising an aqueous continuous phase and a dispersed phase comprising elastomeric polymers; introducing the sealant composition into a subterranean formation; and crosslinking the sealant composition into a gel to form a seal in the subterranean formation, thereby forming an elastic gelled sealant composition, wherein the elastic gellable composition reduces the brittleness of the elastic gelled sealant composition as compared to the sealant composition without the elastic gellable composition. | 04-30-2015 |
| 20150114650 | FLOODING OPERATIONS EMPLOYING CHLORINE DIOXIDE - A method includes introducing a treatment fluid including a first polymer gel into a subterranean formation to generate a production fluid having an aqueous portion and a hydrocarbon portion, treating the aqueous portion of the production fluid with chlorine dioxide to separate additional hydrocarbons from the aqueous portion, and adjusting the viscosity of the treated aqueous portion prior to introducing the treated aqueous portion back into the subterranean formation. | 04-30-2015 |
| 20150122498 | METHOD AND DEVICE FOR CONCENTRATING DISSOLVED SOLIDS IN FLOWBACK AND PRODUCED WATER FROM NATURAL GAS WELLS - A wastewater concentrator a liquid evaporator assembly, a gas-liquid separator, an exhaust assembly, and a flowback water concentrating system. The flowback water concentrating system includes a settling tank fluidly connected to the gas-liquid separator and a supernatant liquid concentration sensor for measuring a concentration of dissolved solids in the supernatant liquid in the settling tank. | 05-07-2015 |
| 20150129226 | Thickening of Fluids - An aqueous fluid, possibly a wellbore fracturing fluid, comprises an aqueous solution or dispersion of a first polymer, which may be polysaccharide, as a thickener and a cross linking agent to enhance the viscosity of the fluid by crosslinking the first polymer, wherein the crosslinking agent is a second polymer comprising at least one polymer chain with phenyl boronate groups distributed along the polymer chain and the phenyl boronic acid groups have nitrogen attached to the phenyl group at a position which is meta relative to the boronate group. | 05-14-2015 |
| 20150129227 | METHOD FOR ENHANCED HYDROCARBON RECOVERY - The invention relates to a method of treating a hydrocarbon containing formation, comprising the following steps: a) preparing an internal olefin sulfonate, comprising sulfonating an internal olefin into sulfonated internal olefin followed by contacting sulfonated internal olefin with a base containing solution resulting in the internal olefin sulfonate, wherein sulfonated internal olefin is contacted with the base containing solution in the presence of a non-ionic surfactant, and/or after step a) but before step b), the internal olefin sulfonate and said non-ionic surfactant are combined; b) transporting an aqueous solution comprising the internal olefin sulfonate and the non-ionic surfactant to the location of the hydrocarbon containing formation; c) providing the internal olefin sulfonate and the non-ionic surfactant to at least a portion of the hydrocarbon containing formation; and d) allowing the internal olefin sulfonate and the non-ionic surfactant to interact with the hydrocarbons in the hydrocarbon containing formation. | 05-14-2015 |
| 20150129228 | SURFACTANT FORMULATION FOR RELEASE OF UNDERGROUND FOSSIL FLUIDS - The present disclosure provides a surfactant formulation for use in treating and recovering fossil fluid from a subterranean formation. The surfactant formulation includes a primary surfactant, a formulation stability agent and injection water. The surfactant formulation may be injected into one or more injection wells located within the subterranean formation and fossil fluids can then be subsequently recovered from one or more producing wells | 05-14-2015 |
| 20150136402 | MODIFIED HYDROCARBON RESINS AS FLUID LOSS ADDITIVES - Methods for treating oil-based drilling fluids with a fluid loss additive that includes one or more hydrocarbon resins. An oil-based drilling fluid and a hydrocarbon resin can be combined to produce a treated oil-based drilling fluid. The hydrocarbon resin can include a polymerized product of a reaction mixture that can include a dicyclopentadiene; at least one member selected from the group consisting of: a dimer of an aliphatic cyclic diene having five carbon atoms, a dimer of an aliphatic non-cyclic diene having five carbon atoms, a monoolefin, a diolefin, or a polyene, each having more than five carbon atoms and no aromatic rings, a C | 05-21-2015 |
| 20150144346 | INTERPOLYMER CROSSLINKED GEL AND METHOD OF USING - Disclosed herein is a gel comprising, polyacrylamide crosslinked with a non-metallic crosslinker, the non-metallic crosslinker comprising a polyamine. A method of making the gel and a method of using the gel are also disclosed. | 05-28-2015 |
| 20150291875 | DESORBANTS FOR ENHANCED OIL RECOVERY - The invention relates to the use of at least one compound corresponding to the following formula: R—O—(—CH2-CH(CH3)-O-)m-(—CH2-CH2-0-)u-H where: R is a hydrocarbon-based group comprising from 6 to 40 carbons; m ranges from 0 to 20; n, which is greater than m, ranges from 5 to 40, in order to inhibit the phenomena of retention of anionic surfactants within an oil-bearing reservoir, in particular within a carbonate or clay reservoir. | 10-15-2015 |
| 20150291901 | COMBINED DEHYDRATION OF GAS AND INHIBITION OF LIQUID FROM A WELL STREAM - A method and system is provided for dehydration of a gas phase and hydrate inhibition of a liquid hydrocarbon phase in a produced multiphase hydrocarbon fluid stream containing water, comprising the steps of:
| 10-15-2015 |
| 20150299554 | Alkylated Polyetheramines as Clay Stabilizing Agents - The present disclosure provides water-based well treatment fluids for use in treating subterranean formations to prevent swelling and/or migration of fines. The water-based well treatment fluid contains an aqueous continuous phase, a clay stabilizing agent consisting of an alkylated polyetheramine and a weighting material. In addition to inhibiting swelling and/or migration, the water-based well treatment fluids are thermally stable, are toxicologically safe, and have exceptional handling properties. | 10-22-2015 |
| 20150299557 | USE OF ORGANOCLAY AS EMULSIFIER IN POLYMERIC GELS FOR WATER PERMEABILITY REDUCTION - Organoclay is used as an alternative emulsifier and reinforcing agent and to enhance the strength of emulsified polymeric gel aqueous solutions and form water in oil emulsions. The stability of the emulsion can be controlled by controlling salinity and the intensity of initial mixing. The new system can be used for water shut-off treatments as well as a relative permeability modifier in high water permeability zones. In addition, the system can tolerate salts much better than classical surfactants. This system will be appropriate for wellbores having high temperature (> | 10-22-2015 |
| 20150299561 | METHOD OF PUMPING AQUEOUS FLUID CONTAINING SURFACE MODIFYING TREATMENT AGENT INTO A WELL - A well treatment fluid contains a surface modifying treatment agent having an anchor and a hydrophobic tail. The surface modifying treatment agent is an organophosphorus acid derivative. After the well treatment fluid is pumped into a well penetrating the subterranean formation, the anchor binds to the surface of the formation. The subterranean formation is a siliceous formation or a metal oxide-containing subterranean formation. The anchor bonds to a Si atom when the formation is a siliceous formation and to the metal of the metal oxide when the formation is a metal oxide-containing formation. After being bound to the surface of the formation, frictional drag within the well is reduced. This allows for faster recovery of formation fluids. The bonding of the surface modifying treatment agent onto the formation may further be enhanced by first pre-treating the formation with an aqueous fluid. By increasing the number of sites for the surface modifying treatment agent to bind onto the surface of the subterranean formation, productivity is improved. | 10-22-2015 |
| 20150307660 | POLYCARBONATE BLOCK COPOLYMERS - The disclosure pertains to amphiphilic block copolymers comprising an aliphatic polycarbonate chain coupled to a hydrophilic polymer. Such amphiphilic polymers may have the formula A-L-B, where A- is a polycarbonate or polyethercarbonate chain having from about 3 to about 500 repeating units, L is a linker moiety and -B is a hydrophilic oligomer having from about 4 to about 200 repeating units. Provided copolymers are useful as surfactants capable of emulsifying aqueous solutions and supercritical carbon dioxide. Provided copolymers also have utility as additives for use in enhanced oil recovery methods. | 10-29-2015 |
| 20150307768 | METHOD AND COMPOSITIONS FOR ENHANCED OIL RECOVERY - A powder composition for use in preparing flooding fluid for use in petroleum recovery from a petroleum-bearing formation includes an oxygen scavenger and a polymer material. Methods for preparing flooding fluid and for petroleum recovery from a petroleum-bearing formation employ the powder composition. | 10-29-2015 |
| 20150315455 | Flash Point Adjustment of Wettability Alteration Chemicals in Hydrocarbon Solvents - Gas and condensate productivities from a hydrocarbon reservoir can be enhanced using a chemical treatment composition. The chemical treatment composition includes a solvent mixture and a wettability alteration chemical. The solvent mixture includes a solvent that is operable to increase the relative permeability of gas within the hydrocarbon reservoir and the wettability alteration chemical is operable to alter the wettability of surfaces of the hydrocarbon reservoir, in each case enhancing the gas and condensate productivities from the hydrocarbon reservoir. The solvent mixture is selected to provide a chemical treatment composition with a flash point of at least 40° C. (104° F.). | 11-05-2015 |
| 20150315457 | COMPOSITION AND METHOD FOR TREATING SUBTERRANEAN FORMATION - A composition and method for performing a viscosity reducing treatment of a subterranean formation. The composition includes a sulfobetaine surfactant. The composition and method can employ viscosity reduction of heavy crude oil in a subterranean formation. | 11-05-2015 |
| 20150315872 | Wellbore Flow-Control Assemblies for Hydrocarbon Wells, and Systems and Methods Including the Same - Wellbore flow-control assemblies define a flow-controlled fluid conduit that selectively conveys a fluid flow, including fluid outflow and fluid inflow, between a subterranean formation and a casing conduit. The wellbore flow-control assemblies include a sacrificial flow-control device that defines a first portion of the flow-controlled fluid conduit and a directional flow-control device that defines a second portion of the flow-controlled fluid conduit. The sacrificial flow-control device resists the fluid flow prior to a flow-initiation event and permits the fluid flow subsequent to the flow-initiation event. The directional flow-control device permits one of fluid outflow and fluid inflow and resists the other. | 11-05-2015 |
| 20150315886 | WELL TREATMENT WITH HIGH SOLIDS CONTENT FLUIDS - A method is given for reducing the flow of a treatment fluid in a well, for example for zonal isolation or for stimulation fluid diversion. The method includes preparing a High Solids Content Fluid (a pumpable slurry containing a carrier fluid and a packed volume fraction of at least 50 per cent solids having a multi-model size distribution), injecting the high solids content fluid into the well, placing the high solids content fluid at the location at which fluid flow is to be decreased, and either reducing the volume or increasing the viscosity of the carrier fluid. Optionally, at least a portion of the solids in the High Solids Content Fluid is subsequently removable to restore fluid flow. | 11-05-2015 |
| 20150315893 | Process for recovering soda values from underground soda deposits - Process for recovering soda values from first and second soda deposits situated respectively in first and second underground cavities containing respectively first and second soda solutions, the second soda solution containing a higher concentration in sodium chloride and/or sodium sulfate than the first soda solution, the process comprising: extracting a stream of first soda solution from the first cavity; introducing the stream of first soda solution in a first process which produces first soda crystals and a first waste purge stream containing a higher concentration in sodium chloride and/or in sodium sulfate than the first soda solution; introducing at least part of the first waste purge stream in the second cavity; extracting a stream of second soda solution from the second cavity; and introducing the stream of second soda solution in a second process which produces second soda crystals which have a higher concentration in sodium chloride and/or sodium sulfate than the first soda crystals. | 11-05-2015 |
| 20150322750 | FLOW DISTRIBUTION ASSEMBLIES FOR PREVENTING SAND SCREEN EROSION - Disclosed are flow distribution assemblies for distributing fluid flow through well screens. One flow distribution assembly includes a bulkhead arranged about a base pipe having one or more flow ports and defining flow conduits in fluid communication with the flow ports, a sand screen arranged about the base pipe and extending axially from the bulkhead, a flow annulus defined between the sand screen and the base pipe, and flow tubes fluidly coupled to the flow conduits and extending axially from the bulkhead within the flow annulus, the flow tubes being configured to place an interior of the base pipe in fluid communication with the flow annulus via the flow ports, wherein the flow tubes distribute a fluid through the at least one sand screen at a plurality of axial locations within the flow annulus. | 11-12-2015 |
| 20150329762 | USE OF NANOPARTICLES AS A LUBRICITY ADDITIVE IN WELL FLUIDS - A use of nanoparticles in a well fluid for improved lubricity is disclosed herein. The nanoparticles are present in the well fluid in low amounts below 5 wt %. The nanoparticles may be formed ex situ and added to the fluid or in situ in the fluid. In one aspect, the well fluid is a drilling fluid. In a further aspect, the well fluid is an invert emulsion based fluid or an aqueous based fluid. | 11-19-2015 |
| 20150329767 | METHODS AND COMPOSITIONS FOR USE IN OIL AND/OR GAS WELLS - Methods and compositions (e.g., 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, an emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives. In some embodiments, a concentrate is provided which may be used to form an emulsion or microemulsion. | 11-19-2015 |
| 20150330158 | APPARATUSES, SYSTEMS, AND METHODS FOR INJECTING FLUIDS INTO A SUBTERRANEAN FORMATION - There is provided apparatuses, systems, and methods for effecting injection of injection fluids into a subterranean formation, including: a bundled plurality of fluid-conducting conduits. | 11-19-2015 |
| 20150330174 | Flow Restrictor - A flow restrictor for restricting flow in an annulus, the flow restrictor comprising a body and a restrictor assembly mounted on the body, wherein the restrictor assembly is actuatable between a run-in configuration and a set configuration in which at least a portion of the restrictor assembly is radially splayed to thereby substantially restrict flow in the annulus, and wherein the flow restrictor is actuatable by fluid flow over the restrictor assembly above a threshold flow rate to actuate the restrictor assembly from the run-in configuration to the set configuration. | 11-19-2015 |
| 20150344769 | SUSPENSIONS INCLUDING ORGANIC BASES FOR ENHANCED OIL RECOVERY AND METHODS OF OBTAINING HYDROCARBONS USING SUCH SUSPENSIONS - Suspensions comprising an organic base and at least one carrier fluid. The organic base comprises an amine group and at least one hydrophobic group attached to the amine group. The at least one hydrophobic group may be functionalized with one or more functional groups. Methods of extracting and obtaining a hydrocarbon material from a subterranean formation or bitumen using the suspension are disclosed. | 12-03-2015 |
| 20150344771 | PREPARATION METHOD, FORMULATION AND APPLICATION OF CHEMICALLY RETARDED MINERAL ACID FOR OILFIELD USE - An aqueous composition comprising a mineral acid, a fixing agent and water present in an amount sufficient to dissolve the mineral acid and the fixing agent. The fixing agent comprises at least one of an amine and/or an amide containing compound having a dipole moment of at least 3 when in the aqueous composition. | 12-03-2015 |
| 20150345259 | METHOD FOR CARBON DIOXIDE SEQUESTRATION - A method for geo-sequestration of a carbon dioxide includes selection of a target water-laden geological formation with low-permeability interbeds, providing an injection well into the formation and injecting supercritical carbon dioxide (SC—CO | 12-03-2015 |
| 20150354298 | COMPLETION FLUID - An aqueous well completion/workover fluid, including a surfactant, at least one salt and an alkaline material, wherein the surfactant comprises a mixture of a phosphate ester and a non ionic ethoxylated alcohol, wherein the fluid has a pH between 6 and 8, and wherein the fluid generates an interfacial tension with crude oil of less than or equal to 1 dyne/cm. The fluid is not harmful to a formation if it penetrates the formation, and further exhibits an excellent detergency which can be beneficial as well. | 12-10-2015 |
| 20150354325 | DEVICE AND METHOD FOR IMPROVING GAS LIFT - A device and method to lower the deepest gas lift location to a deeper location within the wellbore. Providing a bottom lift tool with flexible joints to sting into a side pocket mandrel to access annular high pressure gas. Diverting that gas into the stinger through the bottom lift tool down into the wellbore below the lowest end of the production tubular and the packer and preferably to at least the bottom of the perforations in the casing. | 12-10-2015 |
| 20150354331 | Bottom Discharge Electric Submersible Pump System and Method - A bottom discharge ESP is disposed within a pod casing. The pod casing is adapted to connect to and support the weight of downstream tailpipe tubing sections so the ESP does not have to support the same. The ESP may be suspended within the pod interior space by a supporting tube disposed above the ESP and extending into the pod interior space. The ESP includes a discharge tube with a seal assembly that engages a seal bore formed in the bottom end of the pod and cooperating with an interior surface of the tailpipe tubing to convey pumped injection fluid downward to the tailpipe tubing. Part of the pod casing may be perforated to allow injection fluid to flow into the pod interior space. Alternatively, perforated tubing joints or sliding sleeves may be provided on an upper tube to permit flow of injection fluid to the interior of the pod. | 12-10-2015 |
| 20150361323 | TREATMENT FLUIDS FOR REDUCING SUBTERRANEAN FORMATION DAMAGE - Methods including providing a treatment fluid comprising a base fluid, a wettability altering surfactant, and a chelating agent, wherein the treatment fluid has a pH of at least about 5; introducing the treatment fluid into a subterranean formation; altering a wettability of the subterranean formation from oil-wet to either mixed-wet or water-wet with the wettability altering surfactant; and complexing metal ions in the subterranean formation with the chelating agent. | 12-17-2015 |
| 20150361325 | Method For Recovering Oil - The present invention relates to a process for recovering oil from a subterranean formation by injecting both solid particles and water into the formation. An oil-in-water emulsion that is stabilized by solid particles is formed in the pores of the formation. This emulsion is recovered from the subterranean formation. | 12-17-2015 |
| 20150361758 | Disintegrating Packer Slip/Seal - An annularly shaped structure serves as a support and seal when pushed out on a ramp. A continuous seal in a groove is used on one or two sides to enhance sealing. A separate annular structure for sealing can be disposed adjacent to the shape having alternating longitudinal slots so that each structure is targeted to a different purpose. The structures disintegrate when made of a disintegrating material such as for example a controlled electrolytic material (CEM) so that removal of the barrier can occur after a treating operation such as fracturing where many such barriers are deployed. The slots have enlarged holes at their ends to reduce stress concentration that can lead to cracking. | 12-17-2015 |
| 20150361775 | OILFIELD MATERIAL MIXING AND METERING SYSTEM - An oilfield material reservoir is disclosed as having a body and a base connected to and positioned beneath the body. The body has an upper end, a lower end, a sidewall having a first side and a second side extending between the upper end and the lower end forming a recess, and a partition positioned within the recess adjacent to the lower end and extending between the first and second sides of the sidewall. The base has a discharge opening formed within the lower side, and a plurality of augers extending between the first and second ends. The plurality of augers have opposing-hand flights configured to drive an oilfield material toward the discharge opening of the base. | 12-17-2015 |
| 20150368545 | METHOD FOR ENHANCED RECOVERY OF OIL FROM OIL RESERVOIRS - The present invention provides a method for recovering oil from a subterranean reservoir using waterflooding, wherein the flooding fluid used in the waterflooding process comprises water and a pyruvate-rich xanthan gum having at least 5 weight % pyruvate. The use of a pyruvate-rich xanthan gum is expected to increase the recovery of oil by improving both the oil/water mobility ratio and the sweep efficiency in reservoirs with a high degree of heterogeneity. | 12-24-2015 |
| 20150369007 | Hydraulic Delay Toe Valve System and Method - An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention is a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation. The controlled time delay enables casing integrity testing before fluid is passed through the ports. This time delay also allows multiple valves to be used in the same well casing and provide a focused jetting action to better penetrate a concrete casing lining. | 12-24-2015 |
| 20150369010 | PLUG RETAINER AND METHOD FOR WELLBORE FLUID TREATMENT - A method for fluid treatment of a borehole including a main wellbore, a first wellbore leg extending from the main wellbore and a second wellbore leg extending from the main wellbore, the method includes: running a wellbore tubing string apparatus into the first wellbore leg; conveying a plug into the wellbore tubing string apparatus to actuate a plug-actuated sleeve in the wellbore tubing string apparatus to open a port through the wall of the wellbore tubing string apparatus covered by the sleeve; employing a plug retainer to retain the plug in the tubing string against passing outwardly from the tubing string apparatus; allowing fluids to flow toward surface outwardly from the tubing string apparatus; and performing operations in the second wellbore leg. | 12-24-2015 |
| 20150369011 | Hydraulic Delay Toe Valve System and Method - An apparatus and method for providing a time delay in injection of pressured fluid into a geologic formation. In one aspect the invention is a toe valve activated by fluid pressure that opens ports after a predetermined time interval to allow fluid to pass from a well casing to a formation. The controlled time delay enables casing integrity testing before fluid is passed through the ports. This time delay also allows multiple valves to be used in the same well casing and provide a focused jetting action to better penetrate a concrete casing lining. | 12-24-2015 |
| 20150376983 | WELLBORE SYSTEMS CONFIGURED FOR INSERTION OF FLOW CONTROL DEVICES AND METHODS FOR USE THEREOF - It is sometimes desirable to regulate fluid flow using autonomous inflow control devices (AICDs), but they are not readily configurable in the field. Wellbore systems providing adjustable flow control may comprise: a wellbore pipe having an interior space, an outer surface, and one or more orifices defined in the wellbore pipe and extending between the interior space and the outer surface; a flow control assembly fixedly coupled to the wellbore pipe and comprising one or more flow chambers defined on the outer surface of the wellbore pipe that are in fluid communication with the one or more orifices; a movable cover configured to provide access to the one or more flow chambers; and a bung arranged within at least one of the one or more orifices, the bung being configured to accept an insert therein, the insert being at least one of an AICD, a blank, or any combination thereof. | 12-31-2015 |
| 20150376998 | SYSTEMS AND METHODS FOR INLINE CHEMICAL INJECTION FOR DUMP FLOOD WATER INJECTORS - The present disclosure provides techniques for inline injection of water and chemicals for a dump flood. The techniques include collecting water from a source reservoir into a water collection zone of an adjacent water injection well, and injecting a chemical solution into the water injection well. The water and the chemical solution are then mixed downhole in a mixer, such as a static mixer. The mixed injection fluid is then directly injected into an adjacent target reservoir. | 12-31-2015 |
| 20160009981 | ENHANCED OIL RECOVERY PROCESS TO INJECT LOW-SALINITY WATER ALTERNATING SURFACTANT-GAS IN OIL-WET CARBONATE RESERVOIRS | 01-14-2016 |
| 20160017204 | METHODS AND COMPOSITIONS COMPRISING PARTICLES FOR USE IN OIL AND/OR GAS WELLS - Methods and compositions comprising particles for use in various aspects of the life cycle of an oil and/or gas well are provided. | 01-21-2016 |
| 20160017207 | INTERNAL OLEFIN SULFONATE COMPOSTION - The present invention provides an internal olefin sulfonate composition, comprising water and an internal olefin sulfonate mixture having an average carbon number of at least 20, wherein the internal olefin sulfonate mixture comprises hydroxy sulfonates and alkene sulfonates in a weight ratio of hydroxy sulfonates to alkene sulfonates of at least 3.25. The invention further provides a method of treating a crude oil containing formation. | 01-21-2016 |
| 20160024370 | ZERO-INVASION ACIDIC DRILLING FLUID - A drilling fluid system using retarded acid systems such as gelled acid (VES or polymer) and/or emulsified acid to drill carbonate formations (calcite and dolomite). Foamed acid may be used in low abnormal pressure carbonate reservoirs. The drilling fluid system permits drilling a target hydrocarbon-producing formation with zero-invasion of the drilling fluid system. A method for using the drilling fluid system for fluid loss control during drilling operations. | 01-28-2016 |
| 20160024899 | Method and Apparatus for Zonal Isolation and Selective Treatments of Subterranean Formations - A zonal isolation and treatment tool having a reversible fluid booster pump with a reversible motor, both an upper isolation and a lower isolation packer having an elastic surface, a treatment fluid distributor that provides selective fluid access and an electronics control package that couples to the reversible motor. The method includes introducing the tool into the well bore, inflating the upper and lower isolation packers using well bore fluid, introducing the treatment fluid into the well bore such that it is positioned proximate to the tool, operating the tool such that the treatment fluid is introduced into the isolated well bore volume, and maintaining the isolated well bore volume such that the targeted stratum forms a treated stratum. | 01-28-2016 |
| 20160024915 | SYSTEM AND METHOD FOR DOWNHOLE INORGANIC SCALE MONITORING AND INTERVENTION IN A PRODUCTION WELL - An apparatus for estimating an ambient environment at which inorganic scale will form in a downhole fluid includes a stress chamber disposed in a borehole in a production zone at a location within a specified range of maximum pressure and configured to receive a sample of the fluid from the production zone and to apply an ambient condition to the sample that causes the formation of inorganic scale. An inorganic scale sensor is configured to sense formation of inorganic scale within the chamber and an ambient environment sensor is configured to sense an ambient environment within the chamber at which the formation of inorganic scale occurs. The apparatus further includes a processor configured to receive measurement data from the inorganic scale sensor and the ambient environment sensor and to identify the ambient environment at which the formation of inorganic scale occurs. | 01-28-2016 |
| 20160032170 | POLYMER EMULSIONS FOR USE IN CRUDE OIL RECOVERY - Emulsions of mobility control polymers can be used to increase recovery of crude oil from a subterranean hydrocarbon-containing formation. A flooding fluid comprising the polymer emulsions are injected into a well that is in contact with the subterranean hydrocarbon-containing formation. The polymers can be temporarily cross-linked and have protected shear degradation and improved injectivity into the well; the shear resistance can be measured in terms of viscosity loss due to shear, and the improved injectivity can be measured in terms of the flooding fluid's filter ratio, flow rate, and viscosity. | 02-04-2016 |
| 20160032172 | POLYMERS AND EMULSIONS FOR USE IN OIL AND/OR GAS WELLS - Methods and compositions comprising an emulsion or a microemulsion and a polymer for use in 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. In certain embodiments, the polymer comprises a copolymer comprising an acrylamide. | 02-04-2016 |
| 20160040055 | COMPOSITIONS FOR TREATING SUBTERRANEAN FORMATIONS - A method comprises obtaining or providing a treatment fluid comprising compounds comprising a structure of the formula (I) or (Ia) or compounds of the formula (Ib) and placing the treatment fluid in a subterranean formation. | 02-11-2016 |
| 20160040058 | ACCELERATED SWELLING OF OIL-SWELLABLE ELASTOMETERS IN A WELL - A method of swelling an oil-swellable elastomer in a well comprising the step of: contacting the oil-swellable elastomer in the well with a treatment fluid, wherein the treatment fluid comprises: (A) an oil selected from the group consisting of alkanes and naphtha, wherein the oil comprises hydrocarbons having anywhere in the range of 5 to 21 carbons; (B) an α-olefin having anywhere in the range of 18 to 26 carbons; and (C) an activator for oil-swelling, the activator selected from the group consisting of: ketones, dodecane, terpenes, terpenoids, haloalkanes having from 9 to 20 carbons, and any combination thereof. An oil-swelled elastomer as produced by the method is also contemplated. | 02-11-2016 |
| 20160047172 | IMPROVED FLUID FLOW CONTROL DEVICE - A downhole fluid flow control apparatus is disclosed. The fluid flow control apparatus includes a substantially tubular housing. In one embodiment, the fluid flow control device includes an inner diameter and an outer diameter, the inner diameter having a profile defined by one or more contour lines. The fluid flow control apparatus further includes a plurality of circular orifices defined on the tubular housing. In another embodiment, the fluid flow control apparatus includes a plurality of slotted orifices defined on the tubular housing. | 02-18-2016 |
| 20160047226 | SAMPLING AN OIL COMPOSITION AND DETERMINING MINIMUM MISCIBILITY PRESSURE OF AN OIL COMPOSITON WITH A FLUID - Various embodiments disclosed relate to methods and apparatuses for determining a minimum miscibility pressure of a fluid with and oil composition. In various embodiments, the method can include placing a fluid into a pressure chamber at a first pressure. The pressure chamber can include at least one capillary tube having one end disposed in an oil composition in the pressure chamber. The fluid can include at least one of a gas, a liquid, and a supercritical fluid. The method can include measuring a height of the oil composition in at least one of the capillary tubes. The method can include repeating the measuring for at least one cycle using a second pressure different than the first pressure. The method can include determining the minimum miscibility pressure of the oil composition with the fluid by extrapolating the pressure at a height of the oil in the at least one capillary tube of zero from the two or more measurements of the height of the oil composition in the at least one capillary tube. | 02-18-2016 |
| 20160053575 | Bidirectional Flow Control Device for Facilitating Stimulation Treatments in a Subterranean Formation - Bidirectional flow control device for attachment to a tubular member including a nozzle insert comprising a first sealable surface, the nozzle insert comprising a nozzle passage, and a second sealable surface for mating with the first sealable surface, and a first biasing member seat; a cover plate positioned adjacent the first end of the nozzle insert, the cover plate comprising a production orifice and a plurality of stimulation orifices in fluid communication with a plurality of stimulation passages, the cover plate further comprising a second biasing member seat and a biasing member positioned between the first biasing member seat and the second biasing member seat, the biasing member to exert a biasing force to place first sealable surface and second sealable surface in sealing engagement when internal tubular pressure is below a set-point value. | 02-25-2016 |
| 20160060501 | Methods for Controlling Lost Circulation in A Subterranean Well and Materials Therefor - Method for controlling lost circulation in a subterranean well using oil-dispersible lost-circulation materials which comprise fibers that are coated (or sized) with a lipophilic coupling agent, a lipophilic film-forming polymer or both. The fibers are preferably between about 6 mm and about 25 mm long, and between about 10 μm and about 200 μm in diameter. The fibers may be added to carrier fluids comprising oil-base fluids, synthetic-base fluids, invert-emulsion-base fluids and combinations thereof. The preferred fiber concentration in the carrier fluid is between about 0.55 g/L and about 28.5 g/L. The carrier fluid may be a drilling fluid, a spacer fluid or a lost-circulation pill. | 03-03-2016 |
| 20160068743 | Extraction fluids based on associative polymers and on labile surfactants - The present invention relates to an extraction fluid intended especially for water flooding operations or for controlling the relative permeability (RPM) comprising, in an aqueous medium:
| 03-10-2016 |
| 20160069157 | METHOD AND APPARATUS FOR WELLBORE FLUID TREATMENT - A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore. | 03-10-2016 |
| 20160069159 | MATRIX-FRACTURE INTERFACE CLEANUP METHOD FOR TIGHT SANDSTONE, CARBONATE, AND SHALE RESERVOIRS - The invention is related to a method to clean a matrix-fracture interface of fractured tight sandstone, tight carbonate, and tight shale reservoirs. The method involves the injection of at least one fluid into a reservoir, wherein the fluid is gas, a surfactant, a surfactant solution, or combinations thereof. In some embodiments, the reservoir has previously been stimulated mechanically by hydraulic fracturing. | 03-10-2016 |
| 20160069169 | RESOURCE EXTRACTION SYSTEM AND METHOD - A system and method for extracting a resource from a reservoir repeatedly alternates between injecting a fluid and injecting a gas into the reservoir. A rate and/or an amount of each of the fluid and the gas that is injected into the reservoir is defined by a first fluid-and-gas ratio function that designates different ratios as a function of time. The ratios designate the rate and/or the amount of the fluid that is injected into the reservoir to the rate and/or the amount of the gas that is injected into the reservoir. The rate and/or the amount at which the fluid and/or the gas is injected into the reservoir is changed according to the ratios designated by the first fluid-and-gas ratio function as time progresses. | 03-10-2016 |
| 20160069172 | ENHANCED STEAM EXTRACTION OF IN SITU BITUMEN - A process includes: (a) injecting a steam composition into a subterranean location containing bitumen, the steam composition containing an alkylene glycol ether and steam, wherein the alkylene glycol ether is other than a glycol ether amine; and (b) recovering bitumen from the subterranean location to above the ground. | 03-10-2016 |
| 20160076335 | APPARATUS AND METHOD FOR TREATING A RESERVOIR USING RE-CLOSEABLE SLEEVES - There is provided a flow control apparatus comprising: a housing; a port extending through the housing; a housing passage defined within the housing and configured for fluidly communicating via the port; a flow control member displaceable relative to the port for effecting opening and closing of the port; a retainer housing space, disposed between the housing and the flow control member, and co-operating with the flow control member such that, at least while the flow control member is disposed in the closed position, a sealing interface is disposed between the retainer housing space and the housing passage; and a resilient retainer member, extending from the housing and into the retainer housing space, and configured to releasably engage the flow control member for resisting displacement of the flow control member. | 03-17-2016 |
| 20160076343 | TREATING AND COMPLETION SYSTEM AND METHOD OF TREATING A FORMATION - A method of treating a formation includes, running a first string having at least one first port into a completion string having a plurality of second ports, flowing treating fluid through the first string, and flowing treating fluid through the at least one first port and through at least one of the plurality of second ports and into the formation | 03-17-2016 |
| 20160083642 | A LOW TEMPERATURE STABILIZED FOAM-FORMING COMPOSITION FOR ENHANCED OIL RECOVERY - This invention relates to a foam-forming composition having good low temperature stability and method of use thereof for enhanced oil recovery. Said foam-forming composition comprises an anionic sulfonate surfactant, preferably an alpha-olefin sulfonate, a alkyl ether solvent, and water and is preferably stable to at least −5C. A preferred alkyl ether solvent has the formula C8H18O3, C8H16O3, or mixtures thereof. Preferred alpha-olefin sulfonate have 10 to 18 carbons, preferably 12 carbons. A preferred method for recovering oil from a reservoir comprises the periodic injection of gas and said foam-forming composition into the reservoir and contacting the oil in the reservoir with the foam so as to assist in the recovery of oil from the reservoir. | 03-24-2016 |
| 20160083643 | ENHANCED OIL RECOVERY METHOD EMPLOYING A BIODEGRADABLE BRINE TOLERANT FOAM-FORMING COMPOSITION - This invention relates to a foam-forming composition and method of use thereof for enhanced oil recovery. Said foam-forming composition comprises an anionic sulfonate surfactant wherein the anionic sulfonate surfactant is biodegradable and has low aquatic toxicity. The method for recovering oil from a reservoir comprises the periodic injection of gas and said foam-forming composition into the reservoir and contacting the oil in the reservoir with the foam so as to assist in the recovery of oil from the reservoir. | 03-24-2016 |
| 20160115770 | TREATMENT STRING AND METHOD OF USE THEREOF - A tubular member is presented for treating a subterranean formation, the tubular member being insertable in a wellbore intersecting the subterranean formation and adapted to receive a treatment fluid under pressure. The tubular member comprises at least one assembly having at least one port; a straddle system comprising an upper packer uphole of the at least one assembly and a lower packer downhole of the at least one assembly to isolate an annular interval adjacent the ported assembly between the tubular member and the wellbore; and at least one flow diverter valve positioned uphole from the upper packer for diverting fluid from within the tubular member through an annulus between the tubular member and the wellbore to surface. Methods are further provided for treating a subteranian formation | 04-28-2016 |
| 20160122628 | Y-GRADE NGL STIMULATION FLUIDS - Y-Grade NGL fracturing systems and methods of using Y-Grade NGL stimulation fluids. | 05-05-2016 |
| 20160123117 | METHOD OF TREATMENT DESIGN AND OPTIMIZATION OF SEQUENCED FRACTURING TECHNIQUE - In one aspect, a method of optimizing a sequenced hydraulic fracturing treatment to be performed on a well includes predicting, based on a well model of the well and a hydraulic fracturing treatment schedule, a seal state of a perforation cluster. The method may further include updating, based on the predicted seal state, a pilling operation of a stage of the hydraulic fracturing treatment schedule. The method may further include modifying the sequenced hydraulic fracturing treatment schedule to be performed based on the updated pilling operation. The well model includes a geomechanical model of the well and a geological formation. | 05-05-2016 |
| 20160130924 | HYDRATION APPARATUS AND METHOD - Vessels including an enclosure having an outer perimeter and an interior space, a channel disposed in the interior space, a first port disposed on a surface of the first enclosure at or proximate to a first end of the channel, and a second port disposed on a surface of the first enclosure at or proximate to a second end of the channel, where the channel has a length greater than the shortest distance between the first port and the second port, and where the first port and the second port are in fluid communication with one another. In some cases, the length of the channel is greater than a length of the outer perimeter. Optionally, the vessel may have a second enclosure having an outer perimeter and an interior space with a second channel disposed in the interior space, a third port disposed on a surface of the second enclosure at or proximate to a first end of the second channel, and a fourth port disposed on a surface of the second enclosure at or proximate to a second end of the second channel, where the second port, the third port and fourth port are in fluid communication. In yet some other optional variations, the vessel further includes a plurality of enclosures each having an outer perimeter and an interior space, a channel disposed in the interior space, a port disposed on a surface of the enclosure at or proximate to a first end of the channel, and a port disposed on a surface of the enclosure at or proximate to a second end of the channel, where the channel has a length greater than a shortest distance between the ports, and the second port and the ports disposed on the surface of the plurality of enclosures are in fluid communication. The perimeter shape of the enclosure(s) may be any suitable shape, including, but not limited to, substantially circular, ovate or rectangular. | 05-12-2016 |
| 20160137535 | USE OF PERACETIC ACID/HYDROGEN PEROXIDE AND PEROXIDE-REDUCING AGENTS FOR TREATMENT OF DRILLING FLUIDS, FRAC FLUIDS, FLOWBACK WATER AND DISPOSAL WATER - Methods for the use of peracid compositions having decreased hydrogen peroxide concentration and a UV-blocking agent for various water treatments, including oil- and gas-field operations, and/or other aseptic treatments are disclosed. In numerous aspects, peracetic acid is the preferred peracid and is treated with a peroxide-reducing agent to substantially reduce the hydrogen peroxide content. Methods for using the treated peracid compositions for treatment of drilling fluids, frac fluids, flow back waters and disposal waters are also disclosed for improving water condition, reducing oxidizing damage associated with hydrogen peroxide and/or reducing bacteria infestation | 05-19-2016 |
| 20160138366 | METHOD AND APPARATUS FOR SELECTIVE INJECTION - A method and apparatus for selectively treating different zones in a wellbore includes running a tubular string into the wellbore, the string having at least two housings disposed therein, the housings separated along the string, each housing having a fluid path between an interior of the housing and a zone of interest and each housing having an individual profile for mating with an individual insert and running a second, smaller diameter tubular string into the wellbore, the string including an insert, the insert constructed and arranged to mate with a predetermined one of the plurality of housings and to initially seal the fluid path. | 05-19-2016 |
| 20160138377 | SOLUTION MINING UNDER AN INERT GAS - This method includes providing an cased borehole located within a salt bed, injecting an aqueous liquid into the cased borehole at a first pressure, in order to expose the salt bed to the aqueous liquid, thereby dissolving at least a portion of the salt bed and forming a brine solution within an underground storage volume, withdrawing at least a portion of the brine solution from the underground storage volume, and injecting an inert gas into the cased borehole at a second pressure, in order to provide an inert blanket within the underground storage volume, wherein the second pressure is greater than the first pressure but less than the maximum allowable pressure of the cavern. | 05-19-2016 |
| 20160160105 | ENZYMES FOR REMOVING SULFUROUS COMPOUNDS IN DOWNHOLE FLUIDS - Cysteine synthase or O-Acetyl-L-Serine Sulfhydrylase enzymes, such as those derived from the | 06-09-2016 |
| 20160160580 | ANNULAR FLOW CONTROL DEVICES AND METHODS OF USE - A flow control device includes an annular inner shroud coupled to a work string that defines one or more flow ports therein, and an annular outer shroud also coupled to the work string and radially offset from the inner shroud such that a channel is defined between at least a portion of the inner and outer shrouds. The channel is in fluid communication with at least one of the one or more flow ports and configured to restrict a flow rate of a fluid. The work string has a central axis and the inner and outer shrouds extend longitudinally within the work string. | 06-09-2016 |
| 20160168966 | WELLBORE TREATMENT APPARATUS AND METHOD | 06-16-2016 |
| 20160177163 | ORGANIC-INORGANIC HYBRID POLYMER BASED FLUIDS | 06-23-2016 |
| 20160177658 | PACKER APPARATUSES | 06-23-2016 |
| 20160186042 | ENHANCED OIL RECOVERY PROCESS - A process is provided for recovering oil from a hydrocarbon-bearing formation comprised of hydrocarbons and formation water. The process presented herein includes an oil recovery formulation comprising at least 75 mol % dimethyl sulfide and between 1 mol % and 18 mol % of dimethyl ether, wherein the amount of dimethyl ether in the oil recovery formulation is selected relative to the solubility of dimethyl ether in the formation water. | 06-30-2016 |
| 20160186043 | ENHANCED OIL RECOVERY USING CARBOXYLATE GROUP CONTAINING SURFACTANTS - The invention relates to a method of treating a hydrocarbon containing formation, comprising the following steps: a) providing a composition comprising a surfactant to at least a portion of the hydrocarbon containing formation, wherein the surfactant is a compound of the formula (I) R—O—[R′—O] | 06-30-2016 |
| 20160186544 | SIMULTANEOUS INJECTION AND PRODUCTION WELL SYSTEM - Systems for simultaneously injecting and producing in a well having multiple zones. One system includes a wellbore providing first perforations extending into a first subterranean formation and second perforations extending into a second subterranean formation, a production tubing having influx ports defined therein and an annulus defined between the wellbore and the production tubing, first and second pairs of wellbore isolation devices arranged about the production tubing and axially straddling the first and second perforations to define first and second formation zones, respectively, a first bypass conduit extending between the first pair of wellbore isolation devices, a second bypass conduit extending between the second pair of wellbore isolation devices, and an injection outlet defined on the first bypass conduit for injecting a portion of the fluid into the first subterranean formation and push hydrocarbons toward the second formation zone to be produced. | 06-30-2016 |
| 20160194548 | Method and Use of a Composition for Sand Consolidation in Hydrocarbon Wells | 07-07-2016 |
| 20160200963 | THERMALLY STABLE POLYMERS FOR ENHANCED OIL RECOVERY | 07-14-2016 |
| 20160251932 | Method and Apparatus for Wellbore Fluid Treatment | 09-01-2016 |
| 20160251936 | WELLBORE SYSTEMS WITH ADJUSTABLE FLOW CONTROL AND METHODS FOR USE THEREOF | 09-01-2016 |
| 20160251939 | TOOL FOR OPENING AND CLOSING SLEEVES WITHIN A WELLBORE | 09-01-2016 |
| 20160376171 | SEPARATION OF KINETIC HYDRATE INHIBITORS FROM AN AQUEOUS SOLUTION - The invention relates to a process for treating an aqueous solution from a subterranean formation of an oil and gas operation. The aqueous solution can be removed from the subterranean formation and treated in a heated centrifugal separator. The heated centrifugal separator can separate the kinetic hydrate inhibitor from the aqueous solution, and then the aqueous solution can be reintroduced into the subterranean formation. | 12-29-2016 |
| 20160376490 | Functionalized Nanoparticles as Crosslinking Agents for Sealant Application - A variety of methods and compositions are disclosed, including, in one embodiment, present disclosure relates to treatment of subterranean formations and, in specific examples, to sealant compositions that may be used for creating fluid flow preventing barriers in a subterranean formation. A method may comprise reacting components comprising functionalized silica nanoparticles and a crosslinkable component in a subterranean formation to create a barrier in the subterranean formation, wherein the functionalized silica nanoparticles comprise at least one functional group selected from the group consisting of amino groups, thiol groups, and combinations thereof. | 12-29-2016 |
| 20170233627 | Completion Fluid Friction Reducer | 08-17-2017 |
| 20170233638 | Use of Hexamethylenetetramine Intensifier for High Temperature Emulsified Acid System | 08-17-2017 |
| 20170234089 | Mixing Tank and Method of Use | 08-17-2017 |
| 20190144737 | PRE-FLUSH FOR OIL FOAMERS | 05-16-2019 |
| 20190144742 | FRICTION REDUCERS AND WELL TREATMENT FLUIDS | 05-16-2019 |
| 20220135868 | METHODS AND SYSTEMS FOR THE GENERATION OF STABLE OIL-IN-WATER OR WATER-IN-OIL EMULSION FOR ENHANCED OIL RECOVERY - Systems for generating stable emulsions may employ one or more liquid-liquid ejectors for mixing the oil with water through motive and suction streams to produce the emulsion as a discharge stream. One or more motive tanks may be fluidly coupled to the one or more liquid-liquid ejectors; the one or more motive tanks may supply the one or more liquid-liquid ejectors with a motive fluid. One or more suction tanks may be fluidly coupled to the one or more liquid-liquid ejectors; the one or more suction tanks may supply the one or more liquid-liquid ejectors with a suction fluid. One or more discharge tanks may be fluidly coupled to the one or more liquid-liquid ejectors; the one or more discharge tanks may collect an emulsion from the one or more liquid-liquid ejectors. Additionally, a flow line coupled to the one or more discharge tanks may feed the emulsions into a formation. | 05-05-2022 |
