3275results about "Pipe protection against corrosion/incrustation" patented technology

PCT No. PCT/JP95/02034 Sec. 371 Date May 23, 1997 Sec. 102(e) Date May 23, 1997 PCT Filed Oct. 4, 1995 PCT Pub. No. WO96/10710 PCT Pub. Date Apr. 11, 1996An object of the present invention is to provide galling resistance to a threaded joint used for an oil well pipe. On a thread portion and a metallic sealing portion of the joint, there is provided a manganese phosphate chemical formation coating layer, or alternatively there are provided a nitriding layer of 1 to 20 mu m thickness and a manganese phosphate chemical formation coating layer of 5 to 30 mu m thickness, and also there is coated a solid lubricant which contains powder of molybdenum disulfide or tungsten disulfide and also contains one of epoxy resin, furan resin and polyamide resin as an essential component, and a ratio of composition is maintained at a specific value, so that a solid lubricant coating layer of 10 to 45 mu m thickness can be formed by heating. Due to the above surface treatment, even when the frequency of repetition of fastening and unfastening of the joint is increased, the occurrence of galling can be prevented over a long period of time.

Coating systems which provide corrosion resistance and, optionally, lubrication, for threaded connections are disclosed. The compositions comprise a first coating composition comprising polymer matrices of polyimides or epoxies which are modified with small amounts of a fluorine containing polymer. Also present in the coating compositions are corrosion inhibiting agents and inorganic particles having a mean diameter of between approximately 10 nm and 10 μm. Solid lubricants, which may include at least one of PTFE, HDPE, Graphite, and MoS₂, are optionally added to provide the first coating with a low coefficient of friction. The coating systems may further comprise a second coating composition, comprising a solid lubricant dispersed within an epoxy resin and a solvent. The first and second coating compositions are deposited on at least a portion of at least one of the pin and box members of the threaded connections.

Methods and systems for cleaning and providing barrier coatings to interior walls of piping systems. An entire piping system can be cleaned in one single pass by dry particulates forced by air and the piping system coated in one single pass. Pipes can be protected from water corrosion, erosion and electrolysis. Pipes having diameters of approximately ⅜″ up to approximately 6″ are treatable. Piping systems such as potable water lines, natural gas lines, HVAC, drains, and fire sprinkler systems in homes, apartments, high-rise hotel/resorts, office towers, high-rise apartment and condominiums and schools, can be treated. The coating forms an approximately 4 mils or greater covering inside the pipes. Buildings can return to service within approximately 24 to approximately 96 hours.

A threaded metallic joint has the thread surface of pin (100) and box (200) covered with a coating comprising a first layer (24) laid on the overall surface of the pin member (100), and a second layer (25) laid on part of the surfaces of either one of the pin or box members. In a first aspect, the coating comprises a first layer with high friction and anti-seize properties laid on the overall surface of the pin member (100), and a second layer (25) with low friction properties laid on specific parts of the surfaces of either one of the pin or box members. Preferably the specific surfaces are those which are in reciprocal radial contact during make-up until pin and box reach the point where shoulders (9, 10) abut. The second layer may contain polytetrafluoroethylene (PTFE). In a second aspect the first layer with a high friction and anti-seize properties laid on the overall surface of the box member (200).

Disclosed herein is an article having a surface modified to alter its surface tension property and increase resistance to sand abrasion as characterized by a material volume loss of less than 75 mm³ according to ASTM G65-04 Procedure B. In one embodiment of the method, an intermediate layer is first deposited onto a substrate of the article. At least a substrate on the article is protected by a coating layer, which comprises: an intermediate layer adjacent to the substrate with a thickness of at least 2 mils containing a plurality of pores with a total pore volume of 5 to 50% within a depth of at least 2 mils; and a surface layer comprising a lubricant material deposited onto the intermediate layer. The lubricant material infiltrates at least a portion of the pores for the coating to have the desired surface tension depending on the application.

A pipe thread protector includes a case, a first seal member, and a second seal member. The case is attachable to an end of a pipe to protect a threaded region of the pipe. The case has a cylindrical or frustoconical portion having threads over at least a portion of its length to engage the threaded region of the pipe, and an annular end portion configured to abut a distal end of the pipe. A first seal member is disposed at the cylindrical portion of the case, and a second seal member is disposed at the annular end portion of the case. At least one of the first and second seal members (i) is detachable from the case, and (ii) comprises a material different than a material of the case.

A structural component for use in oil, gas, exploration, refining and petrochemical applications in the form of a pipe system is provided. The pipe system contains at least two pipe sections are that fusion bonded together, each pipe section comprises a plurality of layers, an inner layer in contact with the corrosive petroleum product comprising a thermoplastic material, a structural layer comprising a composite material, and an outer layer comprising a fire resistive material. In one embodiment, the pipe system meets level II fire endurance standard according to IMO A 18/Res.753 fire testing protocol.

Coatings for protecting and insulating fluid and/or gas transport conduits, such as off-shore oil and gas pipelines operating at temperatures of up to 100° C. in water depths above 1,000 metres. The outer surface of the conduit is provided with at least one layer of thermal insulation comprising polystyrene or styrene-based thermoplastic, having low thermal conductivity, high thermal softening point, high compressive strength and high compressive creep resistance.

A lubricating coating composition in which at least one basic lubricant selected from a basic sulfonate, a basic salicylate, and a basic phenate is dissolved in a volatile solvent is applied to the frictional surface of a box and a pin constituting a threaded joint for oil well pipes. The composition may further contain one or more of a thermoplastic resin powder, another lubricant, and an extreme pressure agent. The surface roughness of the frictional surfaces preferably has an Rmax in the range of 5-40 micrometers.

A corrosion-resistant threaded connection including a first tubular member having an outer metal tube of corrosion-prone material and an inner metal lining of corrosion-resistant material, the first tubular member forming a first pin connection having a nose portion comprising a ring of corrosion-resistant material secured, e.g., welded, to the tube of corrosion-prone material, a radially outwardly facing, annularly extending thread-free first pin shoulder being formed on the corrosion-resistant ring, the first member including an externally threaded portion providing male threads, and a second tubular member comprising a metal coupling having a first end and a second end and forming a first box connection and a second box connection, respectively, the coupling including an internally disposed annularly extending metal section of corrosion-resistant material disposed intermediate the ends of the coupling, each of the box connections comprising a radially inwardly facing, annularly extending box shoulder formed on the section of corrosion-resistant material, each of the box connections further including a threaded female portion having threads complementary to the male threads, the pin and box shoulders being sized and configured such that when respective ones of the first pin connections are threadedly received in the first and second box connections, the pin and box shoulders are in metal-to-metal sealing engagement.

A method for forming a field joints between sections of coated or insulated pipe which are to be welded together and incorporated into an undersea pipeline for carrying single or multi-phase fluids such as oil, gas and water. The method includes the application of a liquid epoxy layer which overlaps a lip of the factory-applied FBE coating protruding beyond a chamfered end of the factory-applied insulation layer, and which may be applied over the entire weld joint area. The liquid epoxy layer is partially cured by application of heat, and a layer of powdered adhesive is applied onto the partially cured liquid epoxy layer. The adhesive is subsequently sintered and activated by application of heat to its outer surface. The outer surfaces of the adhesive layer and the chamfers are then preheated and the thermal joint insulation is injection molded over the entire joint area. Throughout the entire method the temperature of the factory-applied FBE coating is maintained below its glass transition temperature so as to avoid weakening the bond between the FBE coating and the underlying steel pipe. The number and sequence of steps can be varied, depending at least partly on whether the liquid epoxy and adhesive layers are applied in a pipe coating facility or in the field.

The invention discloses a full corrosion-resistant connection structure of a steel lining plastic composite pipeline, and belongs to the technical field of connection of the steel lining plastic composite pipeline. The structure comprises a corrosion-resistant ring sleeved on a non-meshing section of an external thread of a steel outer layer, a steel lining plastic composite pipe fitting consisting of a steel outer ring part and a plastic inner ring part, and a composite pipe consisting of the steel outer layer with the external thread, and a plastic inner layer, wherein the external thread consists of a meshing section and the non-meshing section; an annular cavity of which the inner wall is provided with an internal thread section is formed between the steel outer ring part and the plastic inner ring part; the pipe is in threaded connection with the pipe fitting; a solid hot melt adhesive is arranged in the annular cavity; when an alternating magnetic field is formed at the periphery of the joint of the pipe fitting and the pipe, the solid hot melt adhesive is in thread engagement with the steel outer ring part and in sealed connection with the end faces of the steel outer layer and the plastic inner layer; and the corrosion-resistant ring is in sealed connection with the non-meshing section of the pipe. After the scheme is adopted, the problem that the threads of the pipe and the pipe fitting are easily corroded and rusted is solved, and a full corrosion-resistant threaded connection effect is achieved.

Methods and systems for cleaning, coating and sealing leaks in existing pipes, in a single operation. A piping system can be cleaned in one pass by dry particulates forced and pulled by air throughout the piping system by a generator and a vacuum. Pipes can be protected from water corrosion, erosion and electrolysis, extending the life of pipes such as copper, steel, lead, brass, cast iron piping and composite materials. Coatings can be applied to pipes having diameters up to approximately 6″. Leak sealants of at least approximately 4 mils thick can cover insides of pipes, and can include novel mixtures of fillers and epoxy materials, and viscosity levels. A positive pressure can be maintained within the pipes during applications. Piping systems can be returned to service within approximately 96 hours.

Apparatus and methods for integrating a fiber optic cable (116) with a pipeline (104) are described. An example pipeline having an integrated fiber optic cable includes a plurality of pipe sections (119a, 119b), where each of the pipe sections has a thermally insulating outer layer (200, 202) and ends not covered by the outer layer. The ends of each of the pipe sections are welded to respective ends of other pipe sections to form field joints (111a) at the welded ends. The pipeline also includes a fiber optic cable, where first portions (120) of the fiber optic cable are in contact with some of the pipe sections at some of the field joints and where second portions of the fiber optic cable between the first portions are fixed to the outer layer. A coating is applied to cover each of the first portions of the fiber optic cable to integrate the fiber optic cable with the pipeline.

The invention relates to method for forming at least one metal oxide on one or more interior surfaces of closed or partially closed fluid transport or processing systems. The method involves applying at least one metal compound to the interior surfaces to be treated using, for example, one or more traveling applicators, commonly known as “pigs.” Then, the at least one metal compound is converted to at least one metal oxide, such as by heating the surfaces. In some embodiments, the at least one metal oxide provides a protective metal oxide coating adhered to those surfaces. Embodiments of the present invention can be performed in situ on existing fluid processing or transport systems.

The invention relates to the manufacture of protective coatings onto interior surface of long-length tubes or pipes having relatively small diameter, in order to prevent corrosion-, erosion-, or wear damage of said surface. The method for manufacturing a tube comprising an embedded corrosion-resistant and wear-resistant-coating, wherein the tube consists of an external tube layer, a bond layer, a corrosion- and wear-resistant coating, and an internal tube layer, includes: depositing the corrosion- and wear-resistant coating (CWRC) onto outer surface of the internal tube, depositing a bonding material onto CWRC, inserting the internal tube with deposited CWRC and bond material into the external tube to provide an embedded CWRC between external and internal tube layers, and bonding both tubes with the interior CWRC in one solid structure. A crack-healing compound or release compound is additionally deposited onto internal tube before CWRC, which is preferably alumina ceramic or hard thermal-sprayed alloy. CWRC can be multilayer coating that includes said internal tube embedded between CWRC layers.

An iron based hardfacing alloy with an undiluted (all weld material) alloy composition is substantially balanced in order to achieve an hypo-eutectic primary austenitic with secondary martensitic solidification mode. The alloy enables the deposition of substantially crack-free single layers of hardfacing onto industrial components without any post weld treatment. The hardfacing alloy is capable of withstanding abrasion of silicious earth particles when applied to industrial products, such as tool joints, stabilizers and casing and other tubulars used in oil and gas well drilling, and other industrial products.