Extreme Limited Entry Design Improves Distribution Efficiency in Plug-n-Perf Completions: Insights from Fiber-Optic Diagnostics
- Kiran Somanchi (Shell Canada) | James Brewer (Shell Canada) | Alan Reynolds (Shell Canada)
- Document ID
- Society of Petroleum Engineers
- SPE Hydraulic Fracturing Technology Conference and Exhibition, 24–26 January, The Woodlands, Texas, USA
- Publication Date
- Document Type
- Conference Paper
- 2017. Society of Petroleum Engineers
- 4 Facilities Design, Construction and Operation, 2 Well completion, 2.2 Installation and Completion Operations, 2.4.1 Fracture design and containment, 2.5.2 Fracturing Materials (Fluids, Proppant), 2.2.2 Perforating, 4.1 Processing Systems and Design, 4.1.2 Separation and Treating, 2.4 Hydraulic Fracturing, 2.1.3 Completion Equipment
- Plug and Perf, Distributed Acoustic Sensing, Montney, Fiber Optics, Limited Entry
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Limited entry (LE) plug ‘n’ perf (PnP) fracture designs were pioneered in the early 1960s as a cost-effective technique to stimulate multiple pay zones with varying stress regimes (Murphy & Juch, 1960). Conventional completion techniques would involve blanket perforating the entire interval with 4 shots per foot. The technique was revolutionary in that it recommended "limiting" the number of perforations to distribute fracture stimulation fluids into multiple intervals with differing stress regimes. However, diagnostics have shown that LE treatment distribution during the slurry phase is uneven and is highly impacted by several key parameters that may change significantly during treatment. Several papers have been published on the inefficiencies associated with LE design and what can be done to overcome them (Ugueto, Huckabee, Molenaar, Wyker, & Somanchi, 2016) (Somanchi, O' Brien, Huckabee, & Ugueto, 2016).
Shell Canada Ltd. recently tested eXtreme Limited Entry (XLE) designs to determine if additional pressure drop across the perforations would improve treatment distribution. Stages were alternated with differential perforation friction (∆P) pressures of 2,000, 2,500, and 3,000 psi to determine if there was a threshhold ∆P that would result in a more optimal treatment distribution. However, due to wellhead pressure limitations, actual ∆Ps were below the design values. There were no placement issues associated with fewer perforations and higher treatment pressures.
The trial well was completed with thirteen 3-cluster stages. All clusters were evenly spaced at 50 meters and fracture stimulated with a slickwater system with 31 tons/cluster (93T/stage). The fracture stimulation was monitored using an externally clamped fiber-optic (FO) cable. Treatment distribution and production were quantified using Distributed Acoustic Sensing (DAS) (Molenaar & Cox, 2013).
Post-job analysis indicates a 40% improvement in distribution compared to previously stimulated 3-cluster standard LE completions. With the XLE design, 100% of clusters received some proppant. There is a 33% increase in cluster activity at IP90 from the XLE design compared to a previously completed 3-cluster conventional LE well. Improvement in distribution is minimal beyond ∆P of 1200 psi during the pad phase. However, this threshold could be rock-specific and needs to be validated with trials in different play types. Data also suggests that treatment pressure should be maintained at a maximum throughout the pad and slurry placement, within equipment and wellhead limitations. During pad, this is important to ensure breakdown and fracture extension. In the slurry phase, maxing out pressure helps to maintain ∆P across eroding perforations.
In some plays, insufficient ∆P may prevent all clusters from breaking down. In Groundbirch, typically all clusters breakdown and take fluid from the start but screenout as soon as sand hits. Howeever, slurry rate is typically not increased to compensate for the loss in ∆P due to an increase in perf diameter. These factors are largely responsible for the heel-toe bias in LE designs which results in under-treatment of toe clusers. (Ugueto, Huckabee, Molenaar, Wyker, & Somanchi, 2016)
|File Size||2 MB||Number of Pages||11|
In 't Panhuis, P., den Boer, H., Van Der Horst, J., Paleja, R., Randell, D., Joinson, D., … Bartlett, R. (2014, October 27). Flow Monitoring and Production Profiling using DAS. Society of Petroleum Engineers(SPE-170901-MS). doi:10.2118
Van der Horst, J. (2015, December 6). Recent Advances in Fiber Optic Technology for In-Well Production and Injection Profiling. International Petroleum Technology Conference, PTC-18563-MS. doi:10.2523