H2S Losses in Reservoir Fluid Sample Chambers – A Case Study (original) (raw)

Offshore Technology Conference, 2017

Abstract

To ensure proper selection of reservoir completion, subsea and topside production materials of construction and production chemicals, it is imperative to accurately assess the Hydrogen Sulfide (H2S) concentration in produced reservoir fluids. At high reservoir pressures (>10,000 psi), H2S concentration as low as 50 ppm (mole) or less must be quantified. If an offshore production well test cannot be performed, these assessments must be made based on the analysis of open-hole formation testing samples. Open-hole sampling with formation testing equipment only allows for the production of a relatively small amount of reservoir fluid and exposes the reservoir fluid to potential sites for H2S adsorption/reaction during the sampling process. Sites for potential H2S loss include the contact of the reservoir fluid with oil or water based drilling fluids, the formation tester flowline, and within the formation tester sample chamber after isolation downhole. This work focuses on evaluating ...

Sunil Ashtekar hasn't uploaded this paper.

Let Sunil know you want this paper to be uploaded.

Ask for this paper to be uploaded.