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This study aims to provide a theoretical basis to evaluate the suitability and integrity of corrosion pipes.

The three-dimensional models of the P110S oil pipe with local corrosion damage, general corrosion damage, pitting corrosion damage are established based on the API 579 standard using the nonlinear finite element analysis method for parametric research.

The reliability of the model is verified based on the experimental data from the existing literature. The effects of the oil pipe’s size and the corrosion damage’s type on the residual internal pressure strength are simulated and obtained. What’s more, a basic method for predicting the remaining life of corrosion damaged pipes is proposed.

The authors evaluated the residual strength of various corroded tubing, compared the tubing with different corrosion types and proposed a basic method for predicting the remaining life of the corroded tubing from the corrosion depth.

The American Polypenco Inc., a subsidiary of the Polymer Corporation, has recently developed a new and near‐revolutionary non‐metallic industrial tubing material called NYLAFLOW. This article describes its properties and suggests some possible uses.

ALTHOUGH the primary object of this article is to describe processes and plant used in the manufacture of cold drawn seamless steel tubing, it cannot be considered complete without some reference to previous work on the steel, by which it is converted from the solid rolled billet to the hollow bloom, which may be considered as the “raw material” for cold drawing.

This paper aims to establish the downhole CO₂ partial pressure profile calculating method and then to make an economical oil country tubular goods (OCTG) anti-corrosion design. CO₂ partial pressure is the most important parameter to the oil and gas corrosion research for these wells which contain sweet gas of CO₂. However, till now, there has not been a recognized method for calculating this important value. Especially in oil well, CO₂ partial pressure calculation seems more complicated. Based on Dolton partial pressure law and oil gas separation process, CO₂ partial pressure profile calculating method in oil well is proposed. A case study was presented according to the new method, and two kinds of corrosion environment were determined. An experimental research was conducted on N80, 3Cr-L80 and 13Cr-L80 material. Based on the test results, 3Cr-L80 was recommended for downhole tubing. Combined with the field application practice, 3Cr-L80 was proved as a safety and economy anti-corrosion tubing material in this oil field. A proper corrosion parameter (mainly refers to CO₂ partial pressure and temperature) can ensure a safety and economy downhole tubing anti-corrosion design.

Based on Dolton partial pressure law and oil gas separation process, CO₂ partial pressure profile calculating method in oil well is proposed. An experimental research was conducted on N80, 3Cr-L80 and 13Cr-L80 material. A field application practice was used.

It is necessary to calculate the CO₂ partial pressure properly to ensure a safety and economy downhole tubing (or casing) anti-corrosion design.

The gas and oil separation theory and corrosion theory are combined together to give a useful method in downhole tubing anti-corrosion design method.

Outlines how bimetallic tubing can be used to prevent process tubing corrosion. Describes how Sandvik Steel has developed tubes which are used in an industrial urea plant.

The Société Métallurgique de Gerzat has perfected a manufacturing process for aluminium tubes plated on the inside, outside or simultaneously on both surfaces. For A5, A‐M1 (American 3003) and A‐G1 tubes, the plating is carried out with a 2% zinc aluminium alloy which provides protection by electro‐chemical means of the bore of the tube against corrosion in aggressive ambients, particularly those involving running water. The tubes are produced by direct pouring methods, without any welding whatsoever. The plating, therefore, faithfully follows all the deformations which might occur in the tubing and thus maintains all its properties. The tubes can be supplied either tempered or drawn (types varying from ¼ hard to ¾ hard). The range of external diameters varies from 10 to 100 mm., the thicknesses from 0.4 to several millimetres. The thickness of the plating ranges from 0.15 – 0.3 mm. The Société Métallurgique de Gerzat is represented in Britain by Monogram Engineering Services Ltd., Clarendon Road, Watford, Herts.

Corrosion is considered as one of the issues that threaten the safe operation of steam generator (SG) tubing. Some sulfur-related specie can cause corrosion degradation of SG tubing. Sulfur-induced corrosion of SG alloys in high temperature and high-pressure water is one of the most complicated processes. The purpose of this study is to study the effect of reduced sulphur on passive film properties of steam generator (SG) tubing.

In this paper, the effects of reduced sulfur on passive film properties of SG tubing were reviewed from the aspects of thermodynamic calculations and experimental.

Thermodynamic calculations are mainly presented by E-pH diagrams, volt equivalent diagrams and species distribution curves. The stability of sulphur species highly depends on temperature, solution pH, and electrochemical potential. Experimental data indicated that reduced sulfur species can interact with the passive film, which led to changes in film thickness, film structure, semiconductivity and pitting growth rate.

The state-of-the-art discussed in this paper gives basis for resolving engineering problems regarding with sulfur-induced corrosion.

Organic coatings are one of the most widely applied methods for corrosion protection of metallic materials such as the tubing used in sour gas field. However, such coatings usually encounter the risk of failure due to the harsh and complex environment. Therefore, the study of failure of the organic coating is highly significant.

In this paper, the effects of Cl-concentration, HCl content, hydrogen sulfide/carbon dioxide (H₂S/CO₂), temperature and flow rate on the failure of epoxy-phenolic coating on the internal surface of BG90S steel tubing were investigated using adhesion force measurement, metallographic microscope, electrochemistry impedance spectroscopy and Fourier transform infrared spectroscopy.

The results show that the Cl-concentration, HCl content and H₂S/CO₂ do not affect the failure process too much as the ion concentration increased. However, the flow rate at the high temperature is the most important factor affecting the corrosion resistance of the inner coating tubing. With the increase of the flow rate, the pore resistance of the coating shows a decreasing trend, and the rate of decrease in pore resistance is first rapid and then slow. It demonstrates that the penetration speed of the electrolyte solution into the coating varied from fast to slowly. A weakening influence of the flow rate on the penetration failure of the inner coating can be found as the increase of the flow rate. Once the HS-ions penetrate through the coating and reach at the coating/steel interface where H₂ could be formed through the adsorption reaction, the coating failure occurs.

The failure of the coating depends on the penetration rate of water and ions, with the presence of exposed or punctured holes is accelerated and HS- was adsorpted by substrate Fe, and form H2 molecules between the coatings and substrate, that results failure of coatings.

During the past few years the use of plastics piping has increased manyfold, although when compared with the established metallic tubes and pipes its proportion of the market is still relatively insignificant. Several factors, however, are likely to advance the use of plastics piping; these include improvements in the performance of the polymers available, improvements in pipe fabrication and user recognition of the advantages of these products. A further important consideration is that the future economic trends are likely to favour plastics in two ways. Firstly, the general price trend of metals is upwards, while in contrast the increasing production of plastics and improved control of fabrication processes are tending to reduce the price of plastics.

This paper aims to provide an insight into the main parameters that govern corrosion mechanisms in production tubing of oil and gas wells.

Corrosion has been an old concern for the oil industry. None of the three major sectors of the oil industry, namely, upstream, midstream and downstream, are immune of corrosion attacks. However, the upstream sector (oil and gas production facilities) is more vulnerable to corrosion because of its extreme conditions such as high temperature and pressure, multiphase flow, complicated water chemistry, presence of acidic gases, etc. This paper is a general review of the influence of such parameters on corrosion mechanisms of oil and gas wells.

In recent years, many technical papers have been published in this area. However, none of them provide a general review of the all contributing parameters on corrosion under field conditions.

Modeling and corrosion mitigating processes under downhole conditions require a thorough understanding of the influencing parameters. This paper aims to provide an insight into the main parameters that govern corrosion mechanisms in production tubing of oil and gas wells.