An Evaluation of Coiled Tubing Fracturing Compared to Traditional Completion Techniques in Horizontal Wells

Lewis, B.

doi:10.2118/176994-ms

Cited by 4 publications

References 18 publications

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Comparison of Multi-Stage Fracture Placement Methods for Economic Learning and Unconventional Completion Optimization: A Case History

Singh

Soriano

Lal

2017

Day 2 Wed, January 25, 2017

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The two most popular fracture placement methods in unconventional shale with multiple stages fracturing completion are wireline plug-n-perf and pinpoint perforating / fracturing using coiled tubing. The debate regarding which method is better is still unresolved, as each method has its performance and economic advantages, which make the selection decision very challenging for practitioners and decision makers. In the Antelope Shale reservoir in Monterey Formation, each of these two fracture placement methods were implemented for multi-stage fracturing in 4 vertical offset wells to evaluate the benefits and associated risks, and to identify the preferred method for a full field development plan. The plug-n-perf method had multiple clusters perforated with wireline for each frac stage, whereas the coil tubing method utilized sand-jets to create pinpoint perforation holes with single cluster. In this paper, we discuss the lessons learned and results from application of both fracture placement methods in Antelope Shale using key performance and economic indicators, including time efficiency, cost, production, fracture geometry and zonal coverage. The multitude of operational events experienced during these completion executions demonstrated both the associated benefits related to improved efficiency (efficient completion execution without trouble, record number of completions in single day, etc.) and disadvantages in terms of delayed operation (perforation guns not firing, CT parting, multiple fishing operations during drill out of plugs, ineffective perforation cutting, depth control of CT, etc). The results from various diagnostics such as microseismic, tiltmeters, Diagnostic Fracture Injection Test (DFIT), tracers, etc. were used to compare the effective pay zone coverage with multiple fracture stages, fracture geometry and well productivity for both fracture placement methods. For multi-stage fracturing completions in tight rock, an understanding of risks, rewards, and economic impact of both methods is crucial to completion and stimulation strategy.

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Comparison of Multi-Stage Fracture Placement Methods for Economic Learning and Unconventional Completion Optimization: A Case History

Singh

Soriano

Lal

2017

Day 2 Wed, January 25, 2017

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Case History of Completion Optimization in the Utica

Cipolla

Gilbert

Sharma

et al. 2018

Day 3 Thu, January 25, 2018

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This paper details the results from a comprehensive study to evaluate completion effectiveness and optimize field development in the Utica. Optimizing the number and location of perforation clusters, number of stages, and treatment size requires a clear understanding of how these parameters affect fracture geometry and well productivity. The goal of this work was to determine how the number of perforation clusters per stage and treatment size affect fracture geometry and well productivity, and to integrate these results into the overall field development optimization. A comprehensive evaluation of plug and perf (PNP) and controlled entry point (CEP) completions and treatment size was performed using a five-well pad in the Utica (wet gas area). The evaluation included PNP completions with 3-4 perforation clusters and CEP completions with 1-2 perforation clusters. Treatment size was varied by a factor of two to evaluate the effect of fluid volume on fracture length. Microseismic data were gathered on 81 PNP stages and 95 CEP stages. The microseismic data were used to calibrate hydraulic fracture models. Fracture geometries for the five-well pad plus a direct offset well (a six well total of 250+ stages) were discretely gridded in a reservoir simulation model. The reservoir simulation model was calibrated by history matching 14+ months of production data. Proppant Tracer data and DFIT measurements from previous Utica work were used to support the hydraulic fracture modeling and reservoir simulations. The microseismic data provided a clear understanding of the relationship between treatment size and fracture length for each completion scenario. The results indicate that fracture length may be dependent on completion type, with CEP completions showing less fracture length than PNP completions. Simple production comparisons and detailed reservoir simulation history matching showed that (1) well productivity is governed by the number of perforation clusters, with PNP wells outperforming CEP wells and (2) well-to-well communication is evident. This work did NOT identify any gross inefficiencies with PNP completions and suggests that CEP completions do NOT result in better productivity, at least in this Utica pad. The calibrated models were used to optimize perf cluster spacing, treatment size, and well spacing for PNP completions. The optimization results are summarized in the paper, but the focus of the paper is the evaluation of PNP and CEP completions, characterization of hydraulic fracture length-volume relationships, and calibration of hydraulic fracture and reservoir simulation models.

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Conceptual Design and Production Enhancement for Ball-Activated Multi-Stage Fracturing Systems in Deepwater Formations

Bağcı

Flores

Castro

2018

Day 3 Thu, October 18, 2018

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Multi-Zone, Single-Trip (MZST) completions have significantly reduced the time to complete deep wells with long intervals and have been successfully used in Lower Tertiary formations in deep-water Gulf of Mexico (GOM) projects. MZST completion can be used to create the interface with the reservoir and to deliver stimulation treatments typically limited to up to single-digit zones. Additionally, the minimum spacing allowed by standard MZST completions limits the treated zone length. The Lower Tertiary formations encounter high-laminated pay zones, often hydraulically isolated, and with pressure variations across the small spacing length. Therefore, a treatment covering several compartments results in uneven treatment distribution across long intervals. These single-trip systems require a high proppant amount and pressure to complete the sizeable frac-pack jobs required in Lower Tertiary formations. Using ball-activated fracturing sleeves and dedicated fracturing ports, these completion systems allow a larger number of stages over multiple intervals. This method affords more precise placement of stages with reduced spacing down to single-digit feet between zones, a feature that also enables targeting specific pressure characteristics in the reservoir. Completion selection and well performance analysis were conducted to design a new completion system for production enhancement from Lower Tertiary formations. Design and selection of the lower completion system focused on multi-stage fracturing and potential sand control options, and their impact on production. The following systems were studied to estimate and predict the initial production rates: Multi-Zone Single-Trip (MZST) completion, Large Bore Multi-Zone (LBMZ) completion system and Ball-Activated Fracturing Completion System (BAFCS). This paper describes a high-level workflow developed for completion design and selection, fracture modeling to generate 3D fracture geometry and fracturing pressures, wellbore design including tubing stress and movement analysis for fracturing treatments and production systems analysis to generate vertical lift performance/inflow performance relationships (VLP/IPR), and to estimate the initial production rates and flowing bottomhole pressure for sand-free production. The proposed BAFCS used more fracture initiation points (up to 20 stages) in the Lower Tertiary formations when compared to eight individual stages (20 perforation intervals) with MZST and LBMZ completion systems. The more confined fracture geometries were created by using the new proposed multi-stage fracturing system. Predicted BAFCS production rates were higher than those of MZST and LBMZ completion systems. To attain higher production and recovery factors than those achievable with natural depletion, artificial lift options (electrical submersible pumping) were also examined for Lower Tertiary wells.

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An Evaluation of Coiled Tubing Fracturing Compared to Traditional Completion Techniques in Horizontal Wells

Cited by 4 publications

References 18 publications

Comparison of Multi-Stage Fracture Placement Methods for Economic Learning and Unconventional Completion Optimization: A Case History

Comparison of Multi-Stage Fracture Placement Methods for Economic Learning and Unconventional Completion Optimization: A Case History

Case History of Completion Optimization in the Utica

Conceptual Design and Production Enhancement for Ball-Activated Multi-Stage Fracturing Systems in Deepwater Formations

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