Special Implementation of SRP in Failed Existing Artificial Lift System

Abstract

Abstract The robust construction, ease of operation and maintenance of Sucker Rod Pump (SRP) is a stand-alone artificial lift method owning mostly to its simplicity. SRP are widely used positive displacement pump in land and offshore oilfield applications for lifting of heavy, medium or light oil with gas and water. In this paper, one such implementation of SRP is discussed which are simulated for rigless installation with insert anchor in existing failed artificial lift system. The failure of existing artificial lift system such as PCP, ESP or even SRP itself. Causes loss of cumulative production of the asset and thus economic disadvantage. The scheduling of rig to carry replacement based on oil priority further effects this interval which are generally overlooked. In this paper, implementation of SRP in such existing failed artificial lift system is discussed, carried rigless using insert anchor pump. Thus continuation of maintenance of asset production even after failure of artificial lift system. Such rigless installation opens window preferably of installations carried in wells with lower than expected productivity index. Which may have caused the existing system failure due to operation not being in the pumping range. In this paper, firstly simulation is carried as per the well test of recent failed artificial lift system for maximum production rate with maximum plunger size of the existing tubing size for insert anchor and flowing bottom hole pressure (FBHP). Secondly, rigless installation with economic advantage in comparison to installation with rig is discussed. Thirdly, the successful completion of installing SRP in 3 ½" tubing rigless is discussed with various existing failed artificial lift system. The paper evaluates for design and installation of artificial lift method of SRP through rigless flush-by unit with schematics in failed existing artificial lift system. Generally, with passage of time the formation productivity index drops due to various reasons. Thus the added advantage of resetting the pump at any depth along the production tubing, assists further in the location for minimum free gas percentage and hence extended run life, based on actual well test data and fluid level survey. The comparative results between the existing and new installation remain as a database for advantage in scheduling of rigless installation for optimum production. The design results are extensively discussed with schematics for effective rod stress, torque, rod and surface unit loading for a range of production rate.