Abstract Cemented multi-stage fracturing (CMSF) completion was the first of its kind to be implemented in a deep tight gas well. A single-entry (SE) system was first introduced then an upgrade was developed with a multi-entry (ME) system to stimulate gas reservoirs in multi stages. This paper will illustrate the operational efficiency gain from the ME completions and will compare stages and number of fracturing sleeves in terms of injection efficiency and production gains. CMSF systems are alternative to open-hole MSF (OHMSF) systems and plug-and-perf (P&P) systems. All are designed for multi-stage fracturing in targeted laterals to maximize production while reducing the drawdown pressure. CMSF systems are run similar to OHMSF systems with fracturing sleeves/ports but without OH packers to isolate between stages and cement is pumped between stages for isolation. The completion toe opens up by applying a certain pressure and the first stage can be pumped through it. Other stages open through ball drops to activate fracturing sleeves. The number of entries is studied against injection efficiency and production gains. Operational efficiency was improved in ME systems compared to SE systems. One ME well had 10 stimulation stages pumped per design. The toe stage had two entries while remaining 9 stages had three entries per stage. Previously, 9 stages were planned in the SE system and 7 stages were pumped per design while 2 stages were skipped due to low injectivity. Both systems capitalized on cement for isolation between stages and not using OH packers that could fail and cause communication between stages. Additionally, the ME system capitalized to pump all planned stages as more flow area is available. Gas rate is gained as more effective stages are pumped and cost is reduced as less lost time is encountered. It is worth to mention that drilling or completion running issues are significantly reduced for running these CMSF systems even in tight developments compared to OHMSF. Gas wells can even run it without a mechanical caliper. Finally, there should be an optimum number of stages or entries per stage to avoid low injectivity or over design. This paper will show a well that needed more entries and will show another that needed less. Stuck chances are reduced while running the CMSF components as the completion OD is reduced compared to the OHMSF. Fracturing sleeves are placed with the help of petrophysical data and AI caliper log while mechanical calipers can be no longer needed. Finally, production gain is realized, cost is saved, and wellbore exposure time is reduced.
Aloweiny et al. (Tue,) studied this question.
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