Novel Application and First Full Deployment in the World for Gas Lift in Gas Fields

ABSTRACT The Amin rich gas reservoir can be easily interpreted across the entire area of North Oman. It is being identified as an extremely tight, disconnected, low porosity, low permeability, and HPHT reservoir, and thus presents unique challenges to harness its full production potential. Approximately, 15 years after production began with significant pressure depletion below dew point, a significant loss in Well productivity occurred in some of the Wells. Furthermore, during shutdowns or sudden trips of production stations, more Wells faced difficulties to restart again due to mainly, condensate banking and other probable reasons like formation water cross-flow during shut-in, which created a water bank and impaired inflow performance liquid loading due to low Well bore pressure which caused higher static head at the Well tubing. Common practice of Nitrogen lifting (N2) with CTU becoming not economical with increased number of Wells suffering from Liquid loading (2 jobs per well/annum) and represented a major challenge to look for cheaper economic alternatives. To reduce the higher OPEX associated with nitrogen lifting of Wells and improve UR by improving well outflow, multiple options were considered and evaluated thoroughly including extensive study of several artificial lift methods which were thought to defer liquid loading and mitigate kick-off issues such as Foam lifting, Plunger lift, Beam Pump, ESP, Jet Pump and Gas lift (Concentric gas lift). The optimum gas Well de-liquification method has been identified based on the highest UR considering connected GIIP and inflow resistance. The outcome of the study indicated that a gas lift technology combined with Well retubing was recommended as the optimum solution. The injected gas has reduced the density of the liquid resulting in reducing the static head at the tubing which increased the Well pore pressure allowing the Well to flow. In addition, gas lift method is flexible for broad range of production and has no limitation on depth or GLR. A successful robust pilot has been completed in three Wells between 2018-2021 and gave conclusive results. The wells show average initial production of 70 k m3/d of gas post commissioning of gas lift & 20 m3/d condensate. The surface development concept encompasses the development, with long term testing. The outstanding successful outcomes of the pilot succeeding in restoring Wells back with economic prolific production rates have led to expedite a full field implementation plan in three fields covering (33 Wells) in the next 5 years. These Wells have similar sub-surface and surface conditions. This project added a significant economic value of NPV and low UTC. The lifecycle potential gain about 2 MMm3/d gas and about 4 kbbl/d condensate. Potential Opex savings of highly amount mln per annum. This paper will highlight the full story of the Gas lift technology implementation and describe in details the entire process starting from the Well candidate selection screening criteria, concept detailed design, critical success factors, project assurances and controls, Injection rate and operating parameters, facility capex, life time cycle and the result tested gas & condensate and water production. Also, the learning and challenges like halite accumulation effects will be shared along with the proven practical mitigation plan that ensured and sustained Well production resulting to significant project success of the technology.