Publications

The paper elaborates on an in-depth laboratory study and testing of the unique combination of hydrophobic and hydrophilic amine formulations and developments, including the search for polar and non-polar blending to improve the quality of gas lift corrosion inhibitor (GLCI) on various water configurations. Beyond the injection of existing gas corrosion inhibitors (GCI), the foaming and emulsion issue in the gas lift system upon the water-dispersible GCI injection appears, leading to lower fluid flowability and further well production shut-ins. Notably, corrosion due to sweet and sour gas is inevitable to impose an extensive low persistence and performance of incompatible GCI. Hence, it is prime to develop the shortage of deprived GLCI to tackle a similar issue in the gas lift system, particularly in one of the offshore oil and gas plants in North West Java, Indonesia.

Several laboratory tests were utilized to evaluate the performance of the typical novel GLCI, including water characterization and selection, water analysis, and improving the active content of GLCI. While the product formulation solubility and solvent selection are tailored with lower volatility below condensate is critical, the partition, solubility, and foaming test is equally essential to narrow the impact of double amines GLCI in addressing the foaming issue. In this case, the combination chemistries of oil-based fatty acid amine and amine with ethanol derivatives become a pivotal chemical to elevate the inhibition efficiencies at 90% at lower water condensation.

The solubility test reveals the phase of GLCI is wholly separated from the produced water at a lower volume for nearly 15 minutes. The foaming test shows no foam formation, which indicates that double amine depressed the foaming tendency of the GLCI upon mixing with the produced water for nearly 15 seconds. No separation and deposit were observed nor decrease in volume when the mixture of GLCI and produced water was heated at 100°C for 24 hours to provide the thermal stability of the GLCI. Furthermore, the kerosene and produce water were completely separated with no emulsion at the entire temperature and dosage ranges. The flash point and specific gravity of the GLCI are 52°C and 0.863 at 25°C, which are more significant than that of crude oil and condensate samples. Eventually, the partition test showcases the contact time between the aqueous phase and the pipe, which has dramatically improved owing to a change in the chemical polarity.

The field trial of the synthesized GLCI confirms the laboratory outcomes and has been injected across 196 wells in the PHE ONWJ premises. Continuous injection treatment programs are feasible for controlling corrosion attacks in gas-lift pipelines, including the gas-lift well tubing. This work paves the way for the utilization of laboratory screening tests of the selected GLCI technology to secure the gas pipeline integrity and prevent unplanned Lost Production Opportunity (LPO) due to the appearance of foaming and emulsion before the internal corrosion and leak occurs.