Production Enhancement by Replacing a Poor-Boy Gas Lifted Well with a Hydraulic Jet Pumping System

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Authors

Shuaib Ahmed Kalwar (Weatherford International Inc) | Abdul Quddos Awan (Weatherford International Inc) | Khizer Mehmood Khakwani (Ocean Pakistan Limited.)

Publisher

SPE - Society of Petroleum Engineers

Publication Date

November 7, 2017

Source

SPE Symposium: Production Enhancement and Cost Optimisation, 7-8 November, Kuala Lumpur, Malaysia

Paper ID

SPE-189240-MS

Abstract

Artificial lift systems are among the most widely used production technologies in global oil and gas operations. Wells that cannot produce liquids to the surface under their own pressure require lift technologies to enable production. Some liquid wells need lift assistance from the beginning and almost all require it sooner or later.

In this paper, a poor-boy gas lifted well was replaced with a jet pumping system to enhance production. Well –2A was spud in July, 1984 and drilled to 14808 ft TD. After performing Drill Stem Test (DST), the well was completed with dual strings of 3-1/2 inche. It produced from Chorgali/Sakessar formations with an average 3,500 BOPD, 9.0 MMSCFD at 2,500 psi of WHP since 1985. However, the production declined to zero between 1991–1995, the well was revived on production, yet halted again. It was then brought back on production in 2002 and 2004, with the help of poor-boy gas lift, by tubing punches, but the water cut reached 100% during the lift and the well was shut in.

Well –2A was revitalized again on production by poor-boy gas lift, in which gas was injected through the ports of a jet pump Bottom Hole Assembly (BHA), after performing a work-over, where it was completed with a single string. Yet, because of repeated failure of the gas compressors, unavailability of high-pressure compressors and marginal production, the well was put on jet pump. The jet pump was run in hole with 12A Nozzle/Throat combination in free-style after ensuring sufficient liquid level within the wellbore.

Based on the results, a marginal well was optimized with the cumulative production of 820 BPD i.e., an average of 120 BOPD and 700 BWPD, which was higher than the targeted production rates evaluated for this well. A free-style jet pump deployment achieved the expected performance and reliability. Moreover, the jet pump can easily be re-optimized by reversing it out to change the nozzle and/or throat without requiring sick-line job.