Prediction of hydrate formation conditions in subsea pipeline with genetic algorithm

2015 ◽  
Author(s):  
Aijaz Abbasi ◽  
Fakhruldin Mohd Hashim
Keyword(s):  
Genetic Algorithm ◽  
Hydrate Formation ◽  
Subsea Pipeline ◽  
Formation Conditions

scholarly journals Integrating Support Vector Regression with Genetic Algorithm for Hydrate Formation Condition Prediction

Processes ◽  
2020 ◽  
Vol 8 (5) ◽  
pp. 519
Author(s):  
Jie Cao ◽  
Shijie Zhu ◽  
Chao Li ◽  
Bing Han
Keyword(s):  
Genetic Algorithm ◽  
Natural Gas ◽  
Gas Hydrate ◽  
Hydrate Formation ◽  
Support Vector ◽  
Gas Hydrate Formation ◽  
Svm Model ◽  
Data Points ◽  
Formation Conditions ◽  
Relative Molecular Weight

To predict the natural gas hydrate formation conditions quickly and accurately, a novel hybrid genetic algorithm–support vector machine (GA-SVM) model was developed. The input variables of the model are the relative molecular weight of the natural gas (M) and the hydrate formation pressure (P). The output variable is the hydrate formation temperature (T). Among 10 gas samples, 457 of 688 data points were used for training to identify the optimal support vector machine (SVM) model structure. The remaining 231 data points were used to evaluate the generalisation capability of the best trained SVM model. Comparisons with nine other models and analysis of the outlier detection revealed that the GA-SVM model had the smallest average absolute relative deviation (0.04%). Additionally, the proposed GA-SVM model had the smallest amount of outlier data and the best stability in predicting the gas hydrate formation conditions in the gas relative molecular weight range of 15.64–28.97 g/mol and the natural gas pressure range of 367.65–33,948.90 kPa. The present study provides a new approach for accurately predicting the gas hydrate formation conditions.

scholarly journals Hydrate Formation Conditions of Methane Hydrogen Sulfide Mixtures

2014 ◽  
Vol 36 (23) ◽  
pp. 2527-2535 ◽  
Author(s):  
S. Bulbul ◽  
M. Parlaktuna ◽  
T. Mehmetoglu ◽  
U. Karabakal
Keyword(s):  
Hydrogen Sulfide ◽  
Hydrate Formation ◽  
Formation Conditions

Evolving a robust modeling tool for prediction of natural gas hydrate formation conditions

2015 ◽  
Vol 12 ◽  
pp. 45-55 ◽  
Author(s):  
Ebrahim Soroush ◽  
Mohammad Mesbah ◽  
Amin Shokrollahi ◽  
Jake Rozyn ◽  
Moonyong Lee ◽  
...  
Keyword(s):  
Natural Gas ◽  
Gas Hydrate ◽  
Hydrate Formation ◽  
Natural Gas Hydrate ◽  
Modeling Tool ◽  
Robust Modeling ◽  
Gas Hydrate Formation ◽  
Formation Conditions

scholarly journals Flow Assurance in Subsea Pipeline Design - A Case Study of Ghana’s Jubilee and TEN Fields

2019 ◽  
Vol 19 (1) ◽  
pp. 72-85
Author(s):  
S. A. Marfo ◽  
P. Opoku Appau ◽  
J. Acquah ◽  
E. M. Amarfio
Keyword(s):  
Flow Rate ◽  
Hydrate Formation ◽  
Flow Assurance ◽  
Processing Plant ◽  
Subsea Pipeline ◽  
Gas Processing ◽  
Parallel Pipeline ◽  
Exploration And Production ◽  
Insulation Thickness ◽  
Pipeline Design

The increasing exploration and production activities in the offshore Cape Three Point Blocks of Ghana have led to the discovery and development of gas condensate fields in addition to the oil fields which produce significant amount of condensate gas. These discoveries require pipelines to transport the fluids avoiding hydrates and wax formation. This paper focuses on subsea pipeline design using Pipesim software that addresses flow assurance problems associated with transporting condensate gas from the Jubilee and TEN Fields to the Atuabo Gas Processing Plant. It also considered an alternate design that eliminates the need for capacity increase of flowlines for the futuristic highest projected flow rates in 2030. The design comprises of two risers and two flowlines. Hydrate formation temperature was determined to be 72.5 ˚F at a pressure of 3 000 psig. The insulation thickness for flowlines 1 and 2 were determined to be 1.5 in. and 2 in. respectively. The pipe size for flowlines 1 and 2 were determined to be 12 in. and 14 in. respectively. The maximum designed flow rate was determined to be 150 MMSCFD. To meet the highest projected flow rate of 700 MMSCFD in the year 2030 at the processing plant, a 16 in. ID pipeline of 44 km length was placed parallel to the 12 in. ID flowline 1. This parallel pipeline increased the designed flow rate by approximately 4.7 times (705 MMSCFD). The alternate design employs 18 in. and 20 in. ID pipes for flowlines 1 and 2 respectively. Keywords: Condensate Gas; Flowline; Flow Assurance; Hydrate; Pipesim

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