Overview of PCP Lifting Technology Development in Daqing Oilfield

Abstract

This paper presented the development of Progressing Cavity Pump (PCP) technologies in Daqing Oilfield during the past 27 years, covering the successful experiences and lessons learned. The history of PCP lifting technology development was reviewed in the round. Several main PCP techniques were presented in detailed as well, including high efficiency and low profile PCP drivehead, hollow rotor PCP water flushing technique, PCP trouble-shooting technique, and PCP logging technique, etc. Daqing Oilfield was the largest continental oilfield in China developed from 1960. Beam pumping units was the main artificial lift method. To date, there are more than 40,000 beam pumping wells. PCP was applied in Daqing Oilfield from 1983. In the past 27 years, the scale of PCP increased at a higher rate. Till the end of 2010, 6,000 plus PCP wells were applied in Daqing Oilfield. PCP has become the second largest artificial lift method in Daqing Oilfield. To date, a series of PCP products have been developed covering the displacement and lift arrangement for different blocks in Daqing Oilfield. Based on the study and experiences for years, a set of completed PCP system design methodology was also created for water flooding, polymer flooding, ASP flooding and other complicated conditions. The fast improvement of PCP mainly resulted from two respects: Firstly, the quick development of PCP production techniques. The adaptability and reliability of elastomer was improved effectively and matching techniques were developed as well. Secondly, the requirement of low energy consumption and environmental protection in petroleum production policies enhanced the application of PCP technologies considerably. This paper applied a successful case study of a novel technology developed in the mature oilfield which could be a great reference for the industry.

Progressing Cavity Pump as a Solution to Increase Productivity of Highly Viscous Oil Wells With Sand Production: A Case Study of Field X

“…Infl ow Performance Relationship curve to determine the ability of the optimum production rate in well Y using the Vogel method because this well only produces 2 fl uid phases, namely oil and water. While the curve of Tubing Performance Relationship as a determination of the ability of the fl uid reservoir to fl ow from the bottom of the well to the surface using the Hagedorn Brown method (Wanfu et al, 2012). In well Alabaster-1 known reservoir pressure (P r ) is 487,127 psia, well bottom fl ow pressure (P wf ) is 143,775 psia and the production rate is 119.5 BFPD.…”