Hundreds of thousands of concrete bridges and hundreds of billions of tons of concrete require characterization with time for corrosion. Accordingly, protocols for rapid testing and improved field characterization systems that automatically triangulate electrical resistivity and half-cell corrosion potential measurements would be beneficial allowing discrete / periodic mapping of a structure to be performed as well as addressing testing for asphalt covered concrete. Further, it is the low frequency impedance of rebar in concrete that correlates to corrosion state but these are normally time consuming vulnerable to noise. Hence, it would be beneficial to provide a means of making low frequency electrical resistivity measurements rapidly. Further, prior art techniques for electrical rebar measurements require electrical connection be made to the rebar which increases measurement complexity/disruption / repair / cost even when no corrosion is identified. Beneficially a method of determining the state of a rebar without electrical contact is taught.

A non-destructive testing apparatus generates an electric current in a test coupon that is adjacent to the metallic structure. The non-destructive testing apparatus measures the electric current to produce at least one electric current measurement. The non-destructive testing apparatus correlates the at least one electric current measurement with the quantity of a predetermined iron oxide in the test coupon to determine a proxy for the degree of alternating current interference corrosion in the metallic structure.

An evaluation method and system for the corrosion degree of an absorbable stent. The method includes the following steps: obtaining the total number S.sub.0 of stent bars of the absorbable stent at the time zero of implantation (S10); separately obtaining n frames of optical coherence tomography (OCT) images of the absorbable stent at the time x of implantation, wherein x is greater than 0, and n is a natural number greater than 1 (S20); determining, according to the n frames of OCT images, the total number Ni of the stent bars corresponding to each frame of OCT image, wherein i is a natural number greater than or equal to 1 and less than or equal to n; and calculating the total number S.sub.x of the stent bars corresponding to the n frames of OCT images at the time x of implantation (I) (S30); determining a corrosion degree Cij of a jth stent bar in an ith frame of OCT image at the time x of implantation, wherein j is a natural number greater than or equal to 1 and less than or equal to Ni (S40); and calculating an overall corrosion degree Cx of the absorbable stent at the time x of implantation according to the following formula: (II) (S50). The evaluation method can be applied to clinical treatment.

A heat transfer surface monitoring (HTSM) system and cell for direct detection and monitoring of fouling, scaling, corrosion, and pitting of heat transfer surfaces. The system has a heat transfer plate (HTP) that has a heat transfer monitoring surface (HTMS). The system also includes an edge-lit light guide and light source to illuminate the HTMS, a fluid flow channel module, a heating/cooling module, a surface imaging module to view the HTMS, and a system controller. The environment is controlled to mimic the environment within heat exchange equipment, which are indicative of the changes inside heat exchange equipment. Output of signals relating to the HTMS are used as a guide mitigate problems related to the monitored heat exchange equipment. The system can also use a heat exchanger cylindrical tube with slit light guides along the tube, and the surface imaging module views the inner surface of the heat exchanger cylindrical tube.

A coated structure with a monitoring system, the structure comprising a base having a base surface, a coating joined to the base surface in a base interface and extending in a thickness direction to an outer coating surface, a sensor comprising at least one electrode embedded in the coating, an I/O device configured to generate an input signal in the sensor and to read an output signal from the sensor, a data logger configured to log the output signal from the I/O device, and a computer unit configured to use the logged signal from the data logger. To provide improved information related to the condition of the structure or coating, the computer unit is configured to determine at least two separate indexes, each index related to a property of the coating or the structure.

A method and a system for monitoring a mechanical device for internal corrosion are provided. An exemplary method includes placing a sampling thermoelectric polymer sheet (TEPS) on an external surface of the mechanical device to be monitored for internal corrosion, and placing a reference TEPS on an external surface of the mechanical device not susceptible to internal corrosion. A current from the sampling TEPS is measured, and a current from the reference TEPS is measured. Potential internal corrosion is identified from changes between the current from the sampling TEPS and the current from the reference TEPS.

This disclosure relates to the monitoring and detection of corrosion and/or erosion of pipes, vessels, and other components in an industrial facility. The monitoring system may comprise of an arrangement of guided wave (GW) transducers and a longitudinal wave (LW) transducer affixed to the piping component to collectively measure for localized corrosion of the piping component without necessarily requiring a thickness map. The monitoring system may use an intelligent amplified multiplexer/switch to control the operation of the transducers that may be controlled and operated to generate waves in the kilohertz range and megahertz range with the same hardware.

The present application concerns in-situ intrusive probe systems and methods. The probe systems described herein can be installed flush to a hydrocarbon containing structure, such as a pipeline, vessel, or other piping system carrying crude, gas or sour products. The probe systems include hydrogen induced cracking (HIC)-resistant microstructure such that as atomic hydrogen permeates the probe surface, the probe captures recombined hydrogen gas. The pressure of the resultant hydrogen gas buildup is measured and predictions as to the HIC activity of that area can be made.

The disclosed systems and method utilize the autofluorescence, optic imaging, and heat transfer resistance technologies to monitor the same simulated surface area for deposits. The systems and methods may provide continuous monitoring, detection, characterization and quantification of deposits. Utilizing this information, an associated control system may initiate alarms, initiate a chemical treatment operation, and adjust corresponding chemical treatment and preventive protocols to minimize and/or eradicate the issue.

An accelerated life testing (ALT) system for the pressurization of corrosive media, such as seawater, at high pressures and at elevated temperatures (up to about 70° C.) for extended periods of time. The interior of a pressure vessel is coated in an inert ceramic/epoxy coating that provides adequate corrosion protection from the corrosive media. A fabric reinforced nitrile diaphragm separates the corrosive media from hydraulic actuating media, such as oil. The hydraulic actuating media is pressurized, which deforms the diaphragm into the corrosive media, thereby increasing the pressure. The diaphragm and supplementary flouroelastomer seals isolate the corrosive media from pressure generating, monitoring, and safety equipment. The temperature of the entire vessel and contents is maintained by complete immersion in a heated, filtered water bath. The system is particularly useful for ALT experiments on components intended for sea floor and long term deep ocean environment operations at about 6000 psi (41.4 MPa).