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This is Part I of a two-part series intended to provide background and a rational justification or supporting rationale for requirements leading to the development and publication of NACE(1) MR 0175 and ISO(2) 15156. Part I focuses on some of the metallurgical and processing requirements; specifically, Rockwell C 22 scale (HRC) limit, the various acceptable heat treatments and the 1wt% Ni limit for carbon and low alloy steels to minimize the threat of sulfide stress cracking (SSC) in H2S containing environments. Part II describes the testing and rationale behind the use of accelerated laboratory test procedures and their development to differentiate metallurgical behavior in sour environments.
This is Part I of a two-part series intended to narrate the “lost” history leading up to the publication of the first Material Requirement (MR 0175) standard prepared by NACE (now AMPP) and its subsequent auxiliary standards. Part I covers field observations and describe the metallurgical issues the that were being investigated in support of NACE T-1B and 1F committees to develop a sour service materials standard. Part II focuses on the rationale behind the use of accelerated laboratory test procedures and their development used for accelerated testing to differentiate metallurgical behavior in sour environments at near atmospheric pressure. The original SSC test methodologies would later be codified as a Test Method in NACE TM 0177 (1977).
A review of the historical events culminating in NACE MR 0175 will provide a technical basis for the Rockwell C 22 (HRC 22) hardness limit for carbon and low alloy steels, information on the 1%Ni restriction, and heat treatment requirements. By recalling the origins of the MR0175 standard, these papers will also provide justification for their continued existence when designing modern, oil and gas wells and flowlines. As the oil and gas industry continues to innovate and mature, it is imperative to maintain knowledge of the origins of the NACE MR 0175 standard and its intended purpose.
This paper is Part II of a two-part series intended to narrate the history, some of which has been forgotten over time, leading up to the publication of the first Material Requirement (MR-01-75) standard prepared by NACE and its subsequent auxiliary standards. Previously, Part I1 described the field observations and discussed the metallurgical factors that were being investigated by the historical NACE T-1B and 1F committees to support the development a “harmonized” sour service materials standard. In Part II, we focus on the rationale behind the use of accelerated laboratory test procedures and their development to differentiate metallurgical behavior in sour environments.
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TOL corrosion is reported to occur in large diameter wet gas pipeline in stratified flow conditionsdue to low fluid velocities1. With increasing distance from the inlet, the wet gas pipeline becomescooler as it loses heat to the environment. Such cooling causes water, hydrocarbon, and otherhigh vapor pressure species to condense on the pipe wall. The upper part of the pipe willconstantly be supplied with freshly condensed water while the less corrosive water saturatedwith corrosion products will be drained along the pipe wall to the bottom of the line.
Sour corrosion and iron sulphide scale deposition are two common flow assurance issues encountered in oilfields. Sour oil wells typically produce crude along with produced water and a significant amount of acidic gases such as carbon dioxide and hydrogen sulfide. The high pressure and temperature conditions under the downhole tend to cause severe corrosion damage including metal loss and pitting, along with iron sulphide scale deposition. Iron sulfide deposition in sour wells is a corrosion induced scale problem. It potentially causes production decline, restricted well intervention, well shutdown, or even severe consequences towards to the abandoned wells.