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Corrosion Management for Offshore Wet Sour Gas Carbon Steel Pipeline with Closed Loop MEG Regeneration System

Picture for Corrosion Management for Offshore Wet Sour Gas Carbon Steel Pipeline with Closed Loop MEG Regeneration System
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Project A is being developed by the company with two fields about 220 km distance from Bintulu, Sarawak. The fields are classified as sour with estimated H2S concentration up to 5,000 ppm and 3.8 mol% CO2. The two fields are mainly Field A1 and Field A2 with approximately 20km apart. Field A1 will have two dry xmas trees, drilled from the Platform A while Field A2 will be developed with 2 subsea wells and supporting subsea infrastructures.

Product Number: 51323-18996-SG
Author: Chun Ho, Leow, Cheng Ai, Khoo, Hock Guan, Ong
Publication Date: 2023
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$20.00
$20.00

This paper presents corrosion management of a wet sour gas carbon steel export pipeline using continuous and batch corrosion inhibitors with mono-ethylene-glycol (MEG) as the hydrate mitigation strategy operating in NACE MR 0175/ ISO 15156 region 3 (severe sour).1 The wet sour gas carbon steel export pipeline corrosion management via continuous corrosion inhibitor (CI) and batch inhibitors with closed loop MEG regeneration system is rare worldwide. This is especially challenging when the said pipeline is likely be the longest offshore wet sour gas, large diameter carbon steel pipeline, approximately 207 km x 812 mm in the world thus far.
Pipeline corrosion management and hydrate management aspects when being reviewed holistically, it could potentially provide significant cost savings yet safeguarding the overall technical integrity of the pipeline. The overall corrosion management leverages on company many years of involvements in JIP and own operating experience in sour service including the pipeline material specification, corrosion management, inspection, and maintenance philosophy. Reliable correlation between reservoir properties and uncertainties in severe sour service, flow assurance, chemical behaviors, operating experiences, etc. were considered to best represent the operating envelope for this wet sour gas carbon steel pipeline. This includes the comprehensive testing and selection of continuous CI and batch inhibitor, corrosion monitoring, operational pigging, maintenance, and inspection requirements throughout the pipeline field life.

This paper presents corrosion management of a wet sour gas carbon steel export pipeline using continuous and batch corrosion inhibitors with mono-ethylene-glycol (MEG) as the hydrate mitigation strategy operating in NACE MR 0175/ ISO 15156 region 3 (severe sour).1 The wet sour gas carbon steel export pipeline corrosion management via continuous corrosion inhibitor (CI) and batch inhibitors with closed loop MEG regeneration system is rare worldwide. This is especially challenging when the said pipeline is likely be the longest offshore wet sour gas, large diameter carbon steel pipeline, approximately 207 km x 812 mm in the world thus far.
Pipeline corrosion management and hydrate management aspects when being reviewed holistically, it could potentially provide significant cost savings yet safeguarding the overall technical integrity of the pipeline. The overall corrosion management leverages on company many years of involvements in JIP and own operating experience in sour service including the pipeline material specification, corrosion management, inspection, and maintenance philosophy. Reliable correlation between reservoir properties and uncertainties in severe sour service, flow assurance, chemical behaviors, operating experiences, etc. were considered to best represent the operating envelope for this wet sour gas carbon steel pipeline. This includes the comprehensive testing and selection of continuous CI and batch inhibitor, corrosion monitoring, operational pigging, maintenance, and inspection requirements throughout the pipeline field life.

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The hydrocarbon exploration in the ocean and deep sea was started as early as early as the 1850s, when the first drilling was carried out in California, USA. Other early oil explorations activities were later recorded in Pakistan (1886), Peru (1869), India (1890) and Dutch East Indies (1893). The development of an offshore industry is directly related to the development of subsea pipelines as well. As the industry expands towards deeper waters, the pipelines are required to have better materials, designs, operation practices and maintenance strategies to withstand the challenging environments. These pipelines are exposed to elevated temperatures, high pressures, and corrosive fluids.
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