PTTEP's concerns
High water cut and reservoir depletion choked hydrocarbon production from a well that had been a consistent oil producer for several decades. Reservoir analysis determined that significant reserves remained but would require secondary recovery technology, which had been considered uneconomical when the well was originally completed and was considered economically challenging.
What PTTEP considered first
During the planning stage, conventional slickline-conveyed gas lift valve (GLV) stinger systems were considered but eliminated as high risk because of the numerous installations (8) required and the need to replace packoffs every 6 to 12 months. Other technologies were also eliminated because they would require the assistance of a workover rig, making them uneconomical.
