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• W1983722751 abstract "This article, written by Assistant Technology Editor Karen Bybee, contains highlights of paper SPE 124869, ’Low Pressure System for Gas Wells: Do We Need It? How Low Should We Go? A Compression Strategy for Tight Gas Wells in South Texas,’ by Quynhthy Bui, SPE, Larry Harms, SPE, Efren Munoz, SPE, and Joe Becnel, SPE, ConocoPhillips, originally prepared for the 2009 SPE Annual Technical Conference and Exhibition, New Orleans, 4-7 October. The paper has not been peer reviewed. In a large field with thousands of wells of different ages and qualities, determining the optimum operating pressure is a challenging task. This study looks at the Lobo field in south Texas, which has approximately 1,800 tight gas wells currently in production, to determine the effect of pressures on recovery and the benefits vs. costs of compression. Wells were divided into three groups that share similar characteristics and were modeled using integrated-production-modeling tools to evaluate recovery vs. line pressure. Introduction Initial field development began in the late 1970s. As the field matures, reservoir pressure declines, and as a result, so does production. Optimizing production requires optimizing surface pressures. The continuous drilling program, while adding to potential recovery, exacerbates the optimization challenge because the mixture of older and newer wells has a large range of pressure needs. The long lead time of compression projects, combined with the flow and load-up characteristics of numerous wells, can result in a significant range of uncertainty for design volumes. Timing, location, horsepower, capacity, throughput, and compressor configuration are some of the numerous variables that need to be determined, with constantly changing needs. Addressing questions on this issue presented a unique opportunity for a multifunctional team of reservoir, production, facility, and operation disciplines to work out a compression strategy. It was necessary for the team to work together to align goals and production philosophy and to manage a balance between top-priority projects in the short term and longer-term projects. A strategy that balances the costs and benefits of compression for the different types of wells was developed. The full-length paper focuses only on the methodology used to determine the benefits and estimated costs of reduction in wellhead pressure, including timing of compression. Definitions and Descriptions of Process The general characteristics of the wells were evaluated to determine the best modeling methodology. The wells produce from the Lobo Lower Wilcox sands at depths ranging from 7,000 to 13,000 ft. These are typical tight gas plays, with permeabilities from .01 to 1 md and net pays from 15 to 150 ft. The average production rate per well in the field currently is less than 200 Mcf/D." @default.
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• W1983722751 date "2010-11-01" @default.
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• W1983722751 title "A Compression Strategy for Tight Gas Wells in South Texas" @default.
• W1983722751 doi "https://doi.org/10.2118/1110-0086-jpt" @default.
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