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There is big initial and small mean current density for offshore platforms. Sometimes the former is twice of the latter. DNV-RP-B401 suggests minimizing anode size and density. NACE-RP-0176 recommends utilizing more anodes. This paper introduces a new method by wing section sacrificial anode with large surface area in the initial period.
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Iron sulfide scales create well deliverability and integrity problems such as reduced production rates and damage to well tubulars. Chelating agents have scarcely been studied for iron-sulfide dissolution. This paper evaluates EDTA, DTPA, and HEDTA for its iron sulfide (FeS) dissolution capacity and kinetics at 300°F (149°C).
A comparative study of the chelating agents with a low pH (3-5), moderate pH (5-9), and high pH (9-14) determined the optimum pH for the scale treatment. These tests were conducted in glass bottles and a high-temperature autoclave apparatus under anoxic conditions. Results show that the iron-sulfide dissolution increases tremendously at 300°F (149°C) when using chelating agents with a pH>5. At 300°F (149°C), the bond strength is reduced, allowing the chelating agents to remove the metal ion from the solid surface. The ranking of the chelating agents in terms of iron-sulfide scale dissolution capacity and effectiveness was DTPA>EDTA>HEDTA at all pH conditions. The role of chelating agents in iron sulfide dissolution at 300°F (149°C) has not been thoroughly investigated. There is no study that reports the optimum treatment time at that temperature. This paper investigates chelating agents and provides the optimum dissolver composition and treatment time for field operations at high temperature conditions.
Corrosion inhibitors provide a critical barrier to internal corrosion, presenting the most cost-effective form of mitigation and enabling operators to use carbon steel where it would otherwise be impractical. The correct selection and validation of inhibitors is essential to ensure successful field deployment, providing safe and reliable operation. However, the selection and optimization of a corrosion inhibitor for a particular field application is not trivial.
In the first paper, a mixture design matrix of a homologous series of alkyldimethylbenzylammonium chlorides (BAC) was used to assess the performance and facilitate optimization of a mixed surfactant corrosion inhibitor system based on surface coverage and steady state inhibited corrosion rate.1 In this second paper, the approach is extended to include adsorption kinetic analysis, as demonstrated in Woollam and Betancourt for a first-order Langmuir kinetic model.2
Carbon steel (CS) material is widely used for the equipment in oil and gas production industry due to its mechanical properties associated with a relatively low cost, compared to other materials. Depending on the corrosiveness of the fluid that is vehiculated, the use of carbon steel is generally associated with the injection of a corrosion inhibitor (CI) in order to mitigate internal corrosion. Corrosion inhibitors are generally used in continuous injection at an injection rate that is depending on the corrosiveness of the fluid. Based on the operational feedback, the internal standards are recommending for multiphase pipelines CI injection rates in the range of 50 - 70 ppm for temperature below 80°C of and of 150 to 200ppm for temperatures above 100°C. These injection dosages are typical values that are considered in the laboratory tests for the qualification of the CI and they are adjusted on-site based on the monitoring results.
The process of digitalization is widely regarded as one of the last remaining cost-efficiency levers left following a sustained period of pressure to reduce operating costs and enhance efficiency. A new digital platform for seamlessly integrating Corrosion and Chemical Management (CCM) program with online real time monitoring is discussed in this article, refer Figure 1. The key objective is to establish full integration of real-time corrosion data with various parameters related to corrosion control.
Sulfur and acidic impurities in crude oils pose serious hot oil corrosion problems in crude distillation units (CDU) and associated vacuum distillation units (VDU), especially with the increase in processing of lowquality, opportunity crudes. In the range of 200-400˚C, reactive sulfur compounds cause sulfidation corrosion of ferritic carbon and chrome steels in CDU, VDU, and front ends of downstream units operating at hot oil temperatures. Over the same temperature range, naturally occurring carboxylic acids in crudes can be so aggressive that higher alloy, austenitic stainless steels containing >2.5% Mo are required for processing high acid oils.
Management and operating teams, across all industries, but especially inside asset management organizations, must increasingly rely on data-driven assessment and analytics for decision making. Clearly, inefficiency and ineffectiveness associated with manual or poorly optimized business processes and fragmented business management Infrastructures is a barrier to formulating the safest, most efficient and cost effective asset management and operational decisions. According to Deloitte’s digital maturity analysis, the midstream industry and specially the pipeline sector is in its lowest stages of digital adoption (first 20-30% progress).