Production fluid

Production fluid

Production fluid refers to the mixture of water, oil, and silt that is extracted from a specific oil field, such as field "B". This fluid is transported through pipelines to measuring stations, where gas is separated from the mixture. The remaining water, oil, and silt are then directed to a central gathering station for further processing.From: Sand management of small hydrocarbon mature fields: single well case study on field in the western part of the Sava Depression (Croatia) [2022]

Deep Sea Development

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Published in Shashi Shekhar Prasad Singh, Jatin R. Agarwal, Nag Mani, Offshore Operations and Engineering, 2019

Shashi Shekhar Prasad Singh, Jatin R. Agarwal, Nag Mani

The presence of carbon dioxide (CO2), hydrogen sulfide (H2S), and free water in the internal production fluid can cause severe corrosion problems in oil and gas pipelines. Internal corrosion in wells and pipelines is influenced by temperature, CO2 and H2S content, water chemistry, flow velocity, oil or water wetting, and the composition and surface condition of the steel.

Dynamic reliability analysis for residual life assessment of corroded subsea pipelines

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Published in Ships and Offshore Structures, 2021

Reza Aulia, Henry Tan, Srinivas Sriramula

Figure 6 presents a causal network model for pipeline corrosion mechanism, which is widely recognised as the main failure threat for pipelines. Two types of corrosion are considered in this model, i.e. internal corrosion and external corrosion. Multiple internal and external factors and their interactions are required to be considered in the analysis. The presence of carbon dioxide (CO2) and hydrogen-sulphide (H2S) in the production fluid can cause severe internal corrosion problems in oil and gas pipelines, while the external corrosion is mainly affected by seawater condition such as salinity and O2 concentration. The mitigation of corrosion is also considered in this analysis, such as corrosion inhibitor injection, pipe cleaning, utilisation of internal coating, cathodic protection, concrete weight coating and external corrosion coating. The temporal clones (shaded in the figure) represent nodes from the previous time slices. In practical instances, these temporal clones are taken from pipeline operational, inspection and incident history data.

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Dynamic reliability analysis for residual life assessment of corroded subsea pipelines