New Hydraulic-Fracturing Process Enables a Low-Risk, Operationally Efficient Solution While Maximizing Stimulation Effectiveness in Unconventional Reservoirs

Beaman, Daniel; McNeil, Fraser

doi:10.2118/150856-ms

Cited by 2 publications

(1 citation statement)

References 4 publications

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“…A ball is still used to isolate the ports; but, instead of circulation, it is caged downhole in the BHA. The process benefits of DM (risk mitigation and control, screenouts, operational efficiency, water usage, equipment footprint, and time on location) were outlined in comparison to plug and perforation methods by Beaman and McNeil (2012). So, any further savings makes this process an even better improvement over using the conventional plug and perf approach.…”

Section: Time Between Stagesmentioning

confidence: 99%

Benefits of Remote Activation and New Downhole Tool for Pinpoint Coiled Tubing Stimulation Technology

Pawar

Hriscu

Brand

2015

Day 2 Wed, March 25, 2015

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The global demand for energy has led to an industry focused on increasing process efficiency with respect to innovative techniques for hydraulic fracturing stimulation. One such innovative process is coiled tubing (CT) deployed pinpoint stimulation. Pinpoint multistage fracturing with hydrajetting perforation technique is a solution that enables fracture placement in virtually an unlimited number of fracturing stages in long lateral sections, with a single trip into the wellbore. The evolution of pinpoint stimulation technology and its benefits have been recognized in many papers published along the years.In some variations of the pinpoint stimulation technique, the bottomhole assembly (BHA) is activated by ball drop and reverse circulation of the ball. This process has been improved with a new generation design of the BHA, which renders the operation capable of being entirely controlled remotely from the surface using movement of the CT string. The ball drop activation is eliminated. This allows real-time, on-demand control of the tool setting. Based on traditional proven pinpoint solutions and adopting this new way of well stimulation, the pinpoint multistage fracturing method has become more efficient. This improved BHA, in conjunction with a proprietary pinpoint stimulation process, can help reduce water consumption on location and horsepower requirements, reduce idle time between fracturing treatments, reduce pump time per stage, and help prevent ball drop difficulties, all without having to make changes to the fracturing spread, equipment, and CT on location.The improved BHA enables hydrajet perforation, hydraulic fracturing using real-time downhole proppant concentration control, and proppant plugs to be set for zonal isolation. Additionally, multicycle sequences can be repeated in long lateral and vertical wells. It also helps assist centralization of the BHA during perforating operations to help maintain appropriate jet standoff distance. This paper presents the development approach of the aforementioned improved BHA, and a means to manipulate it from the surface. Validation during field testing is also outlined.

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Section: Time Between Stagesmentioning

confidence: 99%

Benefits of Remote Activation and New Downhole Tool for Pinpoint Coiled Tubing Stimulation Technology

Pawar

Hriscu

Brand

2015

Day 2 Wed, March 25, 2015

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Comparison of Single-Entry Coiled Tubing-Activated Frac Sleeves vs. Multi-Cluster Plug-and-Perf Completion in the Permian and Anadarko Basin: A Case Study

Algadi

Castro

Mittal

2015

Day 2 Tue, September 29, 2015

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Maximizing ultimate recovery in unconventional wells presents many completion challenges. Among the most relevant, is consistently initiating multiple dominant fractures in close proximity to each other along the lateral. The most common fracturing method, Plug-and-Perf (PnP), relies on stimulating multiple clusters at once, leaving much of the pay zone unstimulated due to fractures initiating at the path of least resistance instead. These unstimulated sections create gaps in the fracture networks, which result in lower well profitability by hindering production and reducing estimate ultimate recovery (EUR). An alternative completion system, coiled tubing-activated frac sleeves (CTFS), is a method that provides accurate fracture placement and greater efficiency. This paper evaluates the production performance of this single-entry fracturing technique compared to the traditional multi-entry PnP method in the Granite Wash and Bone Spring formations. In this study, production analysis was done to compare performance CTFS vs PnP wells. Monthly well production data was derived from public sources. Decline curve analysis was used to appraise the estimated ultimate reserves for each well compared to the other wells in the immediate surrounding area. To complement the decline curve analysis study, a single stage reservoir simulation study is also included in order to compare the performance of the two completion methods. Three and six clusters for PnP stage and 3 entries for the single-entry completion were first simulated in hydraulic fracturing software. The estimated fracture geometry and conductivities were then used to generate a single stage reservoir simulation model. The properties of the reservoir were based on Wolfcamp formation. The simulation estimated cumulated recovery in 30 years. The results of the study show that the use of the single-entry fracturing technique has improved production in comparison to offset wells that were completed conventionally. In the Bone Spring formation, a well completed with CTFS outperformed top 20% producers in the same formation. In addition, results from fracture modelling and reservoir simulation show that more efficient and evenly distributed fracture networks were achieved by using the single-entry technique. Consequently, production has improved by 12% over the multi-entry technique. Also, long-term performance analysis of the Granite Wash study confirms that the use of CTFS as an alternative to PnP has tripled the estimate ultimate recovery. Hence, the CTFS method improved overall fracture placement and proved to be a more efficient alternative to PnP method. The paper presents novel information by evaluating long-term production data and benefits of single-entry stimulations compared to multiple entry fracturing treatments. Additionally, analysis of actual field data through the use of fracture modeling, reservoir simulation and type well analysis provides new technical insights when comparing fracture geometry, hydrocarbon recovery, and production performance between single and multiple-entry wells.

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New Hydraulic-Fracturing Process Enables a Low-Risk, Operationally Efficient Solution While Maximizing Stimulation Effectiveness in Unconventional Reservoirs

Cited by 2 publications

References 4 publications

Benefits of Remote Activation and New Downhole Tool for Pinpoint Coiled Tubing Stimulation Technology

Benefits of Remote Activation and New Downhole Tool for Pinpoint Coiled Tubing Stimulation Technology

Comparison of Single-Entry Coiled Tubing-Activated Frac Sleeves vs. Multi-Cluster Plug-and-Perf Completion in the Permian and Anadarko Basin: A Case Study

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