PUBLICATIONS RIGHTS RESERVED PUBLICATIONS RIGHTS RESERVED THIS PAPER IS TO BE PRESENTED AT THE INTERNATIONAL TECHNICAL MEETING JOINTLY HOSTED BY THE PETROLEUM SOCIETY OF CIM AND THE SOCIETY OF PETROLEUM ENGINEERS IN CALGARY, JUNE 10 TO 13, 1990. DISCUSSION OF THIS PAPER IS INVITED. SUCH DISCUSSION MAY BE PRESENTED AT THE MEETING AND WILL BE PAPER IS INVITED. SUCH DISCUSSION MAY BE PRESENTED AT THE MEETING AND WILL BE CONSIDERED FOR PUBLICATION IN CIM AND SPE JOURNALS IF FILED IN WRITING WITH THE TECHNICAL PROGRAM CHAIRMAN TO THE CONCLUSION OF THE MEETING.
This paper proposes a variation of 'slug test' for sucker rod pumping oil wells. Application of slug testing simply pumping oil wells. Application of slug testing simply expedites the buildup process. A slug test is conducted by admitting a slug of reservoir liquid such that the hydrostatic head of the wellbore liquid column balances the reservoir pressure; that is, the well kills itself. Bottomhole pressures (BHP) pressure; that is, the well kills itself. Bottomhole pressures (BHP) monitored in such a test have been routinely analyzed by the hydrologists and petroleum engineers alike over the past 35 years.
Although a slug is typically associated with a new well, the same concept can be extended to pumping wells producing for years. A variation of slug test can be conducted on producing for years. A variation of slug test can be conducted on a pumping well by leaving the casinghead valve open and recording pressures either downhole or by using the acoustic method. The data so gathered lends itself to slug test interpretation.
An analysis of wellbore storage phenomenon arising from flow of a two-phase g s/liquid mixture is presented. The analysis shows that a slug test would allow the pressure buildup process to occur much faster than the conventional buildup process to occur much faster than the conventional buildup method wherein a surface shut-in is required. Two tests conducted on the same well by the two methods, using downhole recorders, demonstrate the value of the proposed method. Reservoir parameters computed from the two tests are in very good agreement; thus, lending credence to the method proposed. proposed
Testing sucker-rod pumping wells in North America is a demanding task. The long-duration storage arising from two reservoir transmissivity and/or energy necessitates a long test duration. Often tests conducted over five to seven days are required to furnish interpretable data. If formation characteristics dictate further increase in shut-in time, low-rate wells may prove to be economically unattractive for additional test duration.
Methods have been proposed to enhance test interpretation, which has often led to the reduction of test duration. By using sandface rates together with pressure, convolution, rate-normalization and deconvolution methods have been used to interpret pumping well data. In this work we propose to reduce the test duration by performing a variation of slug test and analyzing the data using the slug test interpretation technique.
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