Cemented-Multistage-Sleeve Completion Improves Efficiency of Fracture Stimulation
- Adam Wilson (JPT Editorial Manager)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- May 2013
- Document Type
- Journal Paper
- 154 - 156
- 2013. Society of Petroleum Engineers
- 1 in the last 30 days
- 205 since 2007
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This article, written by Editorial Manager Adam Wilson, contains highlights of paper SPE 163842, "Cemented Multistage Sleeve Completion Improves Efficiency of Fracture Stimulation in an Eagle Ford Shale Well," Glenn Adcock, Sanchez Oil and Gas, and Ben Wellhoefer, SPE, Said Daher, and Eric Fruge, Halliburton, prepared for the 2013 SPE Hydraulic Fracturing Technology Conference, The Woodlands, Texas, 4-6 February. The paper has not been peer reviewed.
The Eagle Ford shale in Zavala County, Texas, is similar to many high-carbonate-content oil-shale formations. As with other shale plays, the industry has preferred using cemented lateral sections as the primary means of fracture-stage isolation, coupled with the plug-and-perforate (PAP) horizontal-completion technique. An alternative completion method, cemented multistage sleeves (CMSSs), recently improved efficiency and reduced completion cycle time. The 16-stage stimulation operation was completed in 24 hours with continuous pumping compared with an average of 3 days for PAP.
This paper highlights the key well (Fig. 1) that successfully implemented the new CMSS completion technique. The key well has been compared to averages from wells using the PAP technique to illustrate how the CMSS technique was able to achieve the completion goals while dramatically increasing completion efficiency. The subject well was drilled to a measured depth (MD) of 11,965 ft, with a lateral length greater than 5,913 ft, and was completed using 16 stages of CMSS technology to fracture stimulate the entire lateral section, which was placed in the Eagle Ford shale. The CMSS technology allowed for 3.80 million lbm of proppant to be placed with 2,901,000 gal of fluid to fracture stimulate the wellbore at an average rate of 54 bbl/min. The 15 stages of stimulation were completed in just 24 hours with continuous pumping operations, compared with an estimated 3 days for a PAP completion and 5 days for previous wells in Fayette County, Texas.
A major challenge in unconventional reservoirs is developing more-efficient integrated completion methods to improve well economics and lower the cost per barrel of oil equivalent (BOE).
Wellbores previously completed with the PAP technique in Fayette County took an average of 5 days. These wells contained 15–20 fracture stages using a fracture design similar to that of the subject well. The challenge of reducing the completion cycle time was seen as an opportunity to improve efficiency and well economics. However, production must not be sacrificed. CMSS completion was used to evaluate whether the technique could achieve both goals.
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