Abstract: A method of controlling deposit buildup comprises generating a gas by reacting an active material in a gas generating element with a fluid that contacts the gas generating element; and controlling deposit buildup with the generated gas.

Abstract: The present invention is concerned with the treatment of produced water, that may be obtained from a chemically enhanced oil recovery process using viscosity-increasing polymeric compounds. Said treatment comprises particularly the steps of obtaining a produced water, such as from an oil-water mixture recovered from an oil-bearing formation, wherein the produced water comprises the viscosity-increasing polymeric compounds; and, of directing the produced water to a specific filtration device, and subjecting the produced water to filtration, for obtaining a retentate stream and a permeate stream. Said process allows particularly obtaining a permeate comprising the viscosity-increasing polymeric compounds, said permeate being substantially free of suspended solids, free oil and emulsified oil.

Abstract: The invention provides for the use of at least one aromatic acid compound of formula i), or a salt thereof, as a water tracer; wherein n is 0, 1 or 2, R1 to R5 are each independently H, alkyl or alkoxy and wherein at least one of R1 to R5 is alkoxy. The invention further provides for a method of monitoring the flow of water within a structure having an inflow point and an outflow point, where the method comprises; a) introducing at least a one tracer of formula i) into said inflow point; b) collecting fluid at said outflow point; and c) measuring the presence and/or concentration of said tracer in said fluid collected at said outflow point over time.

Abstract: Method and apparatus for surveying the downhole environment in a steam stimulated well such as a Steam Assisted Gravity Draining well are described. One method comprises interrogating an optic fibre (104) arranged along the path of a well shaft (202, 204) within a steam stimulated well with optical radiation. At least one downhole steam pulse is generated and data gathered from the fibre (104) in response to the steam pulse is gathered and processed to provide an indication of the acoustic signals detected by at least one longitudinal sensing portion of the fibre (104). In some examples, the processed data can be used to determine at least one characteristic of the steam chamber (210).

Abstract: The present disclosure provides a method for hydraulic fracturing of a formation penetrated by a wellbore, the method comprising: providing a proppant and a two-component adhesive; injecting a proppant-free fracturing fluid into the wellbore to form a fracture in the formation; pulse-injecting the fracturing fluid into the wellbore, wherein pulse-injection provides for at least one injection pulse of the proppant-laden fracturing fluid comprising the two-component adhesive and at least one injection pulse of the proppant-free fracturing fluid, wherein the proppant is characterized by at least one of the following properties: the resistance of the proppant to crushing is lower than the rock closure pressure; when a pressure of 20.7 MPa is applied to this proppant, at least 5 wt. % of particles with a size of less than 100 ?m are formed; the size distribution of the proppant is 10-1,000 ?m; the sphericity and/or roundness of the proppant is less than 0.6; the solubility of the proppant in acids is 5-20 wt.

Abstract: A method for inhibiting the permeation of water in an extraction well of a hydrocarbon fluid from an underground reservoir is described. The method includes the injection of at least one treatment fluid into the underground reservoir. The treatment fluid contains at least one emulsion or dispersion in an organic solvent of at least one copolymer of a first monomer of an acrylic monomer or a methacrylic monomer, and a second monomer having at least one ethylene unsaturation and at least one polyoxyethylene chain. The emulsion or dispersion of the copolymer used in the method is also described.

Abstract: Methods include introducing a multistage treatment fluid into one or more intervals of a wellbore, wherein the treatment fluid contains one or more stages of a polymer-forming composition and one or more stages of a spacer fluid and initiating polymerization of the one or more stages of polymer-forming composition. Methods may include designing a multistage treatment fluid containing one or more stages of a polymer-forming composition and one or more stages of a spacer fluid, wherein or more stages of the polymer-forming composition comprises a thermosetting polymer; and pumping the multistage treatment fluid into a wellbore, wherein the pumping rate is determined by constructing a model based upon (a) the minimum pumping rate determined from the critical reaction temperature and the downhole temperature, (b) the fracture closing time, (c) the temperature within one or more fractures, and (d) the maximum pumping rate.

Abstract: Methods for servicing a hydrocarbon well using natural gas in a well intervention operation can include preparing a working fluid having a composition containing about 10 wt % to 100 wt % of a gas phase natural gas, where the quantity and composition of the natural gas is selected so that under specified well intervention conditions, the natural gas and a liquid phase recovery target material form a mixture in the condensing vapor-gas or vapor-gas part of the mixture's phase envelope. During the well intervention operation and at the specified well intervention conditions, the method can include injecting the working fluid into the well, contacting the working fluid with the liquid phase recovery target material, vaporizing the recovery target material, and forming a homogeneous gas phase well mixture of the recovery target material and natural gas. At least a portion of the homogenous gas phase well mixture can be recovered at surface.

Abstract: The embodiments of the present disclosure relate to increasing fracture network complexity within a subterranean formation using a plurality of fluid stages where one or more of such fluid stages utilizes a liquid gas treatment fluid. The embodiments described herein allow creation or extension of a dominant fracture and branch fractures extending therefrom at one or both of the near-wellbore region and/or the far-field region of a fracture network, thereby enhancing fracture network complexity.

Abstract: Methods and systems for delivering EOR substances and determining their efficiency in real time, or near real time, are disclosed. The systems and methods of the present disclosure are especially important in determining petrophysical information about the reservoir as well as the in-situ effect of substances on enhanced oil recovery.

Abstract: A tracer method for online monitoring of downhole zonal contributions of oil, condensate, gas, or water mass flux of a production flow in a petroleum production well, includes arranging distinct tracer carrier systems, each in different production zones in said well, the distinct tracer carrier systems arranged for releasing unique tracers to a fluid of the production zones, the tracers having affinity after downhole release to separate phases of oil, condensate, gas, or water, using an online tracer monitor, conducting sampling of tracer concentrations for at least one of the tracers in said zonal mass fluxes at a high sampling rate, based on said concentration values, estimating the corresponding zonal tracer fluxes for each delivery data point and using said one or more estimated zonal mass fluxes to control one or more Petro Technical processes.

Abstract: Methods, compositions, and systems for cementing are included. The method comprises providing a cement composition comprising calcium-aluminate cement, water, a cement set retarder, and a cement set activator. The method further comprises introducing the cement composition into a subterranean formation and allowing the cement composition to set in the subterranean formation. The cement composition has a thickening time of about two hours or longer.

Abstract: A lost circulation material (LCM) that includes whole date palm seeds. The whole date palm seeds LCM includes date palm seeds having lengths greater than 22.6 millimeters (mm), date palm seeds having lengths in the range of 16 mm to 22.6 mm, and date palm seeds having lengths in the range of 1 mm to less than 16 mm. Method of manufacturing the whole date palm seeds LCM include washing and drying whole date palm seeds, such that the drying includes air-drying, hot rolling, and cooling. Methods of reducing lost circulation are also provided.

Abstract: Described are methods and compositions for treating a subterranean formation. The method comprising introducing into the subterranean formation via a well-bore a diverter composition, the diverter composition comprising a combination of at least one deformable particle and at least one non-deformable particle; and allowing the diverter composition to block the flow of at least a portion of a treatment fluid from a first location within the well-bore to a second location.

Abstract: Embodiments relate to the use of alkali aluminates and alkali silicates with cement kiln dust to form a settable composition for use in subterranean operations. An embodiment provides a method comprising: introducing a settable composition comprising cement kiln dust, an alkali aluminate, an alkali silicate, and an aqueous carrier fluid into a subterranean formation; and allowing the settable composition to set and thereby reduce fluid flow through a portion of the subterranean formation.

Abstract: Polyelectrolyte nanoparticles are generated to stabilize foam for use in enhanced oil recovery. Stability is further enhanced by optimizing pH and a ratio of polycationic and polyanioinic materials, resulting in stronger and longer lasting foams in the presence of crude oil. Use of these nanoparticles results in negligible damage to formation permeability.

Abstract: The invention includes a method of extending an oil and gas system effective stimulated reservoir volume by performing the steps of adding a brine resistant silicon dioxide nanoparticle dispersion to oil well treatment fluids. This method is found to increase initial production rates of an oil well by over 20.0% as compared to wells either not treated with the brine resistant silicon dioxide nanoparticle dispersion technology or treated by conventional nano-emulsion surfactants.

Abstract: Liners may be cemented in a well bore contaminated with an oil-based or synthetic fluid by injecting an aqueous cleaning fluid into the well, energizing the cleaning fluid to displace fluids present in an annulus between the liner and the bore and to create turbulent flow of the cleaning fluid in the annulus, and injecting a cementitious slurry into the annulus after the cleaning fluid. The cleaning fluid comprises a weighting agent, a suspending agent, a surfactant, and nut shell particulates. The turbulent flow of the cleaning fluid through the annulus is effective to remove oily residues left by the oil-based or synthetic fluid.

Abstract: A well completion assembly and method including apparatus for setting a liner hanger, screens and liner within a wellbore, performing an acid treatment and cementing a liner in a single trip.

Abstract: An injection and downhole-mixing system and method mix two or more components downhole in a wellbore. The system delivers two or more components via fluidly separated delivery channels from the surface into a downhole injection point of the wellbore wherein they are mixed and injected into the wellbore to form a solidifying isolation mixture therein at or about the downhole injection point. After set, the isolation mixture forms a solid, impermeable barrier in the wellbore. The components for forming such barriers may be epoxies, polymers, resins, resin-based gypsum cements, and the like.