143 results about "Scale deposition" patented technology

It has been discovered that certain fracturing fluid compositions can be used to fracture a subterranean formation and be permitted to stay within the formation for a relatively extended period of time, for example 28 days or more, before being flowed back or produced. At least two embodiments are envisioned, a bacteria-containing formulation and an anti-bacterial formulation. Both systems would be expected to prevent the potential of the fluid to oil wet the formulation (water block condition) by keeping the formation water wet through the use of water wetting surfactants or solvents. Additionally, both formulations would control reservoir crude souring (H₂S generation by in situ sulfate-reducing bacteria), reservoir plugging (via slime biopolymers generated by in situ microbes, inorganic scale deposition like calcium carbonate or barium sulfate, and clay fines migration).

Scale deposition on a heat transfer surface in a liquid system such as a heat exchanger is estimated by directing of small portion of the liquid flow through a test cell, consisting of a sensor positioned on and projecting through a conduit wall. The sensor consists of a conductive block containing a heater and having a heated wetted test surface that is flush with the inside of the conduit wall and in contact with the flow through the conduit. Within the conductive block are two temperature sensors which are at different distances from the heated wetted test surface and the heater. The periphery of the apparatus is designed to reduce heat flow through the periphery and allow greater heat flow through the heated wetted test surface. By comparing the temperature differential between the two temperature sensors to the differential when no scale is present, the presence of and amount of scale can be determined, based on reduced heat transfer through the heated wetted surface caused by the accumulated scale. The change in the temperature differential is directly proportional to the scale thickness for a given type of scale. When the thickness of the scale is determined by another means, the nature of the scale can be implied. The sensitivity of the measurement can be adjusted to accommodate a very wide range of bulk liquid or ambient temperature via adjustment of the heat flux through the provided secondary heat flux path.

A packer fluid is provided for use with a wellbore fluid in an annulus or casing bore, having an aqueous portion which contains additives for preventing corrosion, microbiological activity, salt and scale deposition, and an environmentally-acceptable capping fluid which resides at a top of the wellbore to act as freeze protection and as thermal insulation in a the frost penetration layer. The additives in the packer fluid are particularly selected to exist in the aqueous additive fluid and in the wellbore fluid and to be substantially immiscible with the capping fluid and thereby prevent significant migration of the additives into the capping fluid which would compromise its environmental acceptability.

The invention relates to a low-phosphorus water treatment composition, which comprises the following compositions in part by weight: 1 to 3 parts of phosphorus carboxylate, 1 to 30 parts of dirt dispersion agent and 1 to 5 parts of bactericide and algicide. When the concentration multiple is 2 to 6, the corrosion rate and the scale deposition rate of a circulating cooling water system of carbon steel and copper pipelines are all smaller than circulating water quality monitoring and controlling indexes, the industrial water is saved, the environmental pollution is reduced, and the low-phosphorus water treatment composition is widely applied to similar circulating cooling water systems in chemical engineering, petrifaction, steel, electric power and the like, and has great social and economic benefits and promotion value.

A new process for ion exchange softening of water used in Once-Through Steam Generators (OTSGs) by recovering and using the salt content of the blowdown water from the OTSG to regenerate the softener resin is provided, thus eliminating the cost for commercial regenerant salt that would otherwise be needed. Further, the very high purity of the salt recovered in the blowdown inherently results in the production of softened water with hardness leakage levels that are an order of magnitude lower than can be attained using commercial salt, thus reducing scale deposit potential and improving operating efficiency and reliability of the OTSG.

The invention provides a heat pump-type hot-water supply device which includes a heat source-side heat pump unit having a radiation heat exchanger for radiating heat from refrigerant by condensing therefrigerant. The hot-water supply device further includes a hot-water supply unit having a water tank where water is contained, water supply piping for supplying external water into the water tank, water circulation piping communicating with both a bottom section and an upper section of the water tank and circulating water in the bottom section to the upper section of the water tank in a bypassing manner, an absorption heat exchanger located in the middle of the water circulation piping and joined to the radiation heat exchanger of the heat source-side heat pump unit such that the absorptionheat exchanger can absorb heat, and a hot-water supply unit for supplying hot water in the upper section of the water tank to the outside. The water supply piping is branched off into a first water supply route and a second water supply route. The first water supply route supplies, without treatment, the water supplied from the outside into the water tank, and the second water supply route supplies the water from the outside into the water tank after improving the quality of the water by a water quality adjustment unit so that the water does not produce scale. Either or both of the water supply routes are used appropriately depending on the quality of water supplied. As a result, scale deposition is suppressed.

The invention belongs to the technical field of non-volatile memories, in particular to a resistance change memory with an optimized resistance change characteristic and a preparation method thereof. In the resistance change memory provided by the invention, hafnium oxide and aluminum oxide films growing by an atomic layer deposition method are used as functional layers, and the optimization of the resistance change characteristic is achieved by adjusting the ratio of thicknesses of the hafnium oxide film and the aluminum oxide film. The preparation method comprises the following steps of: growing the hafnium oxide film with fixed thickness on a bottom electrode by using the atomic layer deposition method, and growing the aluminum oxide films with different thicknesses so as to obtain the resistance change memories with different characteristics. By a single atomic-scale deposition growth technology, the accuracy of preparing a resistance change memory device can be accurately controlled, the technological precision is improved and thermal budget is reduced.

A gas/liquid contact media for use in an evaporative cooler has a fibrous material structure impregnated with a polymer-based continuous phase designed to have solubility and interfacial tension properties that promote intimate wetting with in service water while inhibiting scale deposition, and an overall cationic charge on the polymer to repel positively charged particles or ions in the water in order to further prevent scale build-up on the media.

The present invention provides a method and system for controlling mineral scale deposition from a formation fluid. The rate at which scaling is occurring is measured in real time using an attenuated total reflectance probe and a photometer. The results are then used to determine whether to increase, decrease or leave unchanged addition of anti-scaling additives.

The invention relates to a binary compound flooding compound and a preparation method thereof, mainly solving the problems that the oil displacement agent containing surface active agents has poor oil displacement efficiency and high using concentration under the high-temperature and high-salt conditions, and corrosion and scale deposition to a stratum and an oil well, caused by alkali in the ternary compound flooding, happen in the prior art. The binary compound flooding compound comprises the following components in percentage by weight: (1) 0.01-5.0 percent of N,N-bi fatty acyl group diamine neopentanoic acid di-polyoxyethylene ether bisulphonate; (2) 0.01-3.0 percent of polymer; (3) 92.0-99.98 percent of formation water, wherein in the general molecular formula of the component (1), R1 is C9-C17 alkyl group, R2 is C2-C6 alkyl group, n is adding composite number of ethoxy groups (EO) and is one integer from 2-7; M is one metal ion of K, Na or Li; the polymer is selected from one ofpolyacrylamide with superhigh molecular weight (viscosityaverage molecular weight is 25,000,000), temperature-resisting and salt-resisting polymer or xanthogen gum, and water is selected from the formation water of the oil field. By the technical scheme, the problems are better solved, and the binary compound flooding compound is suitable for tertiary oil recovery production in the oil field.

The invention relates to an oil displacement compound for tertiary oil recovery and a preparation method thereof, mainly aiming at solving the problems that oil displacement agent containing surface active agents has poor oil displacement efficiency and high using concentration under the high-temperature and high-salt conditions, and corrosion and scale deposition to a stratum and an oil well, caused by alkali in the ternary compound flooding, happen in the prior art. The oil displacement compound for tertiary oil recovery comprises the following components according to mass percentage: (1) 0.01-5.0 percent of N,N-bi fatty acyl group diamine neopentanoic acid di-polyoxyethylene ether bisulphonate; (2) 0.01-3.0 percent of polymer; (3) 92.0-99.98 percent of formation water, wherein in the general molecular formula of the component (1), R1 is C9-C17 alkyl group, R2 is C2-C6 alkyl group, n is composite number of ethoxy groups (EO) and is one integer from 2-7; M is one metal ion of K, Na or Li; the polymer is selected from one of polyacrylamide with superhigh molecular weight (viscosityaverage molecular weight is 25,000,000), temperature resisting salt-resisting polymer or xanthogen gum, and water is selected from the formation water of the oil field. By the technical scheme, the problems are better solved, and the oil displacement compound is suitable for tertiary oil recovery production in the oil field.

The invention discloses a descaling agent used for a hydrogenation device and the preparation method and the application thereof, and solves the coking and scale deposition of the relevant equipment during the petroleum refining process, such as a hydrogenation device reactor, a heating furnace, and a heat exchanger. The general formula of the hydrogenation descaling agent is shown as the formula (1), wherein, R is C8-C20 alkyl; R2 is H, R1 is C1-C24 alkyl, alkoxy or aryl; or both of the R1 and the R2 are C1-C15 alkyl, alkoxy or aryl. Through adopting the descaling agent of the invention, not only the coking and scale deposition can be inhibited, but also the production is simple and easy, and the descaling agent is harmless to the environment.

The invention relates to a polymer-surfactant binary compound oil displacement method, which mainly solves the problems of low oil displacement efficiency and high using concentration of a surfactant-containing oil displacement agent under high temperature and high salt conditions in the prior art and the corrosion and scale deposition of a formation and an oil well due to alkali in alkali-surfactant-polymer compound flooding. By the polymer-surfactant binary compound oil displacement method, underground dehydrated crude oil is contacted with an oil displacement composition and crude oil in arock core is fully displaced under the conditions that the oil displacement temperature is more than or equal to 85 DEG C, the total mineralization of formation water is more than or equal to 16,000mg/L, and the total content of Ca<2+> and Mg<2+> in the formation water is more than or equal to 450mg/L, wherein the oil displacement composition comprises the following components in percentage by mass: (1) 0.01 to 5.0 percent of N,N-difatty acyl diamine dimethylpropanoic acid dipolyoxyethylene ether disulfonate, (2) 0.01 to 3.0 percent of polymer, and (3) 92.0 to 99.98 percent of formation water. Through the technical scheme, the problems are well solved, and the method can be used for the tertiary oil recovery production of an oil field.

The invention discloses a 20 DEG C-gasification vacuum superconductive radiator which comprises radiating fins, wherein the interiors of the radiating fins are communicated to form a completely closed vacuum cavity; the bottom of the cavity is penetrated with a heating pipe; and the cavity is filled with partial superconductive liquid gasified at 20 DEG C. Hot water is led into the heating pipe, then the superconductive liquid absorbs heat to gasify and rises to the upper parts of the radiating fins to condense, and a large quantity of phase change heat is released and diffused to surroundings so as to achieve the purpose of heating; and the condensed superconductive liquid flows back to the lower parts along the inner wall of the cavity and continues to be heated to form a heat-transfer cycle. The device adopts the low-boiling-point 20 DEG C-gasification superconductive liquid, and gasification can be realized at 20 DEG C. The heat transfer starting speed is high, and the vacuum superconductive radiator is particularly suitable for an independent heating system taking a family as a unit. The system needs less cycling hot water, thus water resources are saved, meanwhile, the utilization rate of heat energy is improved, and the purpose of saving energy is also achieved. Scale depositions are not generated in the process of use, and the heat transfer efficiency cannot be reduced after long-term use; and the structure is firm, the tightness is good, thus the service life is effectively prolonged.

The invention relates to an oil displacement method for tertiary oil recovery, which mainly aims to solve the problems that the oil displacement agent containing surface active agents has poor oil displacement efficiency and high using concentration under the high-temperature and high-salt conditions, and corrosion and scale deposition to a stratum and an oil well, caused by alkali in the ternarycompound flooding, happen in the prior art. By the oil displacement method for tertiary oil recovery, underground dehydration crude oil is contacted with an oil displacement compound in the formationwater under the conditions that the oil displacement temperature is more than or equal to 85 DEG C, the total mineralization is more than or equal to 16000mg/L and the sum of Ca2+ and Mg2 is more than or equal to 450mg/L, so that the crude oil in a core can be fully displaced, wherein the oil displacement compound comprises the following components according to mass percentage: (1) 0.01-5.0 percent of N,N-bi fatty acyl group diamine neopentanoic acid di-polyoxyethylene ether bisulphonate; (2) 0.01-3.0 percent of polymer; (3) 92.0-99.98 percent of formation water. By adopting the technical scheme, the problems can be better solved and the method is suitable for tertiary oil recovery production in the oil field.

The invention discloses a scale and corrosion inhibitor and a preparation method thereof. The problems of low concentration multiple of circulating water, large water consumption, large discharge capacity, danger caused by adding sulfuric acid to regulate the pH, high phosphorus content of the scale and corrosion inhibitor and environmental pollution in the prior art are solved. The scale and corrosion inhibitor disclosed by the invention is composed of the following components in percentage by weight: 5-10% of hydroxyl ethidene phosphonic acid, 10-20% of 2-phosphine carboxylic acid-1.2.4- tricarboxylic acid, 10-20% of polyamino polyether methylene phosphonate, 20-40% of acrylic acid-2- acrylamide-2- methylpropanesulfonic acid, 1-5% of nonylphenol polyoxyethylene ether, 5-10% of zinc sulfate heptahydrate, 1-5% of benzotriazole and 10-30% of pure water. The invention further provides a preparation method of the scale and corrosion inhibitor. The scale and corrosion inhibitor disclosed by the invention is low in zinc salt and phosphorus salt contents and is capable of preventing the scale deposition on one hand and reducing the water pollution on the other side, thereby being beneficial to environmental protection.

One exemplary embodiment can be a process for removing one or more scale deposits formed on a surface. The process can include contacting the surface with a composition for a period of time sufficient to remove the scale deposits that comprise coke or metal sulfides or mixtures thereof. Generally, the composition includes an effective amount of an organic acid and/or a salt thereof, and an effective amount of an oxidizing agent.

Geothermal brine always contains some carbon dioxide in solution. Separating steam from geothermal brine removes the carbon dioxide, sharply increasing the pH of the brine and causing precipitation of pH sensitive minerals, including calcium carbonate, magnesium silicate and other metal silicates, clays, and metal sulfides. The binary heat exchanger in a steam-binary hybrid geothermal power plant is especially sensitive to scale deposition from flashed geothermal brine, and application of expensive scale inhibitors is required.

Deposition of scale in the binary heat exchanger can be controlled by separating a small amount of gas-rich vapor from the brine before the main stage of steam separation, and combining this gas rich vapor with the flashed brine before in enters the binary heat exchanger. The carbon dioxide thus added to the brine will decrease pH, decreasing or completely blocking precipitation and deposition of pH sensitive minerals as scale.

The invention relates to a disulfonate gemini surfactant with high temperature and salt resistance and a preparation method thereof, mainly solving problems in the prior art that the oil driving agent containing the surfactant has poor oil displacement efficiency and high concentration of use under the condition of high temperature and salt, alkali takes the corrosion and the scale deposition to the ground floor and the oil well in ASP (alkali, surfactant and polymer) driving. The invention better solves the problems by taking the technical scheme, in which N,N-bisfatty acyl diamine dimethyl propanoic acid dipolyoxyethylene ether disulfonate with the molecular formula of FORMULA is adopted, wherein M is any one of metal ions of potassium, sodium and lithium, R1 is alkyl group of C9-C17, R2 is alkyl group of C2-C6, n is the addition number of ethoxy (EO) group and is any one integer of 2-7. The invention can be used in the production of tertiary oil recovery.

A method for processing of a lignocellulosic feedstock is provided comprising exposing lignocellulosic feedstock to acid in a reactor to hydrolyze at least hemicellulose present in said lignocellulosic feedstock, wherein during said exposing, a scale deposit comprising lignin forms on the inner surface of said reactor; and treating the scale deposit with an alkali solution at a temperature between about 140° C. and about 250° C. so as to remove scale. Also provided is a method for reducing scale deposit that forms on process equipment during a stage of reacting a lignocellulosic feedstock with acid.

The invention relates to a surfactant polymer composition for oil displacement, and a preparation method and application thereof in tertiary oil recovery, and mainly solves the problems of poor oil displacement efficiency in the high-temperature high-salt reservoir, and corrosion and scale deposition damage of three-element composite displacement to the stratum and oil well in the prior art. The surfactant polymer composition for oil displacement comprises the following components in parts by weight: (1) 1 part of surfactant for oil displacement and (2) 0.01-0.1 part of polymer. The molecular general formula of the component (1) is disclosed in the specification, wherein R is C8-C40 alkyl group, R1 and R2 are independently selected from C1-C4 alkylidene group, n+m=2-100, and x=1-100; and the polymer is selected from at least one of ultrahigh-molecular-weight polyacrylamide, temperature-resistant salt-resistant polymer A and xanthan gum. The technical scheme well solves the problems, and can be used in tertiary oil recovery production of oilfields.

A method for scavenging hydrogen sulfides from hydrocarbon or aqueous streams and/or reducing or inhibiting solids or scale formation comprising introducing an additive made up of architectured materials such as star polymers, hyperbranched polymers, and dendrimers that may be used alone or in conjunction with aldehyde-based, triazine-based and/or metal-based hydrogen sulfide scavengers to an aqueous or hydrocarbon stream. A treated fluid comprising a fluid containing hydrogen sulfide and an additive for scavenging hydrogen sulfide or reducing or inhibiting solids and scale formation made up of architectured materials such as star polymers, hyperbranched polymers, and dendrimers. The fluid may further include aldehyde-based, triazine-based and/or metal-based hydrogen sulfide scavengers.

The invention relates to daily hardware, in particular to a manufacturing method of a ceramic vacuum cup. A layer of ceramic is applied to the inner container of a stainless steel vacuum cup, so that the thermal insulation performance of the stainless steel vacuum cup is effectively improved, water scale deposition is avoided and the cleanliness of the vacuum cup is improved.