Perforation Cluster Efficiency of Cemented Plug and Perf Limited Entry Completions; Insights from Fiber Optics Diagnostics

C., Gustavo A. Ugueto; Huckabee, Paul; Molenaar, Mathieu M.; Wyker, Brendan; Somanchi, Kiran

doi:10.2118/179124-ms

Cited by 133 publications

(17 citation statements)

References 10 publications

(4 reference statements)

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“…As previous field observations [16][17][18] and numerical studies [19][20][21] showed, multistage hydraulic fractures might not propagate uniformly, yet planar and biwing fractures are assumed in the model. The hydraulic fractures described in the reservoir model implies hydraulically induced and also propped fractures which indeed contribute fluid production of stimulated wells.…”

Section: 2mentioning

confidence: 95%

“…The presented study only utilizes production history data and reservoir simulation to calibrate the hydraulic fracture parameters. However, integrating recently advanced measurements and techniques such as distributed acoustic sensor (DAS), distributed temperature sensor (DTS) [17,28,29], and seismic wave information [30][31][32] would definitely help better understand geometry and properties of hydraulic fractures.…”

Section: Parametersmentioning

confidence: 99%

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Stimulated Reservoir Volume Characterization and Optimum Lateral Well Spacing Study of Two-Well Pad: Midland Basin Case Study

Park

Janova²

2020

Geofluids

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This paper introduces a flow simulation-based reservoir modeling study of a two-well pad with long production history and identical completion parameters in the Midland Basin. The study includes building geologic model, history matching, well performance prediction, and finding optimum lateral well spacing in terms of oil volume and economic metrics. The reservoir model was constructed based on a geologic model, integrating well logs, and core data near the target area. Next, a sensitivity analysis was performed on the reservoir simulation model to better understand influential parameters on simulation results. The following history matching was conducted with the satisfactory quality, less than 10% of global error, and after the model calibration ranges of history matching parameters have substantially reduced. The population-based history matching algorithm provides the ensemble of the history-matched model, and the top 50 history-matched models were selected to predict the range of Estimate Ultimate Recovery (EUR), showing that P50 of oil EUR is within the acceptable range of the deterministic EUR estimates. With the best history-matched model, we investigated lateral well spacing sensitivity of the pad in terms of the maximum recovery volume and economic benefit. The results show that, given the current completion design, the well spacing tighter than the current practice in the area is less effective regarding the oil volume recovery. However, economic metrics suggest that the additional monetary value can be realized with 150% of current development assumption. The presented workflow provides a systematic approach to find the optimum lateral well spacing in terms of volume and economic metrics per one section given economic assumptions, and the workflow can be readily repeated to evaluate spacing optimization in other acreage.

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Section: 2mentioning

confidence: 95%

Section: Parametersmentioning

confidence: 99%

Stimulated Reservoir Volume Characterization and Optimum Lateral Well Spacing Study of Two-Well Pad: Midland Basin Case Study

Park

Janova²

2020

Geofluids

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“…Finally, Ugueto et al. (2016) conclude that only half or two thirds of the perforation clusters are properly fractured or produced at significant rates after integrating distributed temperature sensing (DTS) and DAS with hydraulic fracture stimulation treatment data for five wells with a total of 120 perforation clusters.…”

Section: Introductionmentioning

confidence: 99%

Laboratory Experiments Contrasting Growth of Uniformly and Nonuniformly Spaced Hydraulic Fractures

2021

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Because of major advances in hydraulic fracturing and horizontal drilling technology, vast tracts of gas bearing shale formations have become a significant source of hydrocarbon production in North America and beyond. These formations are called unconventional resources because they cannot be developed and produced by conventional production methods. As a result of their low permeability, higher intensity operations such as drilling a horizontal wellbore in the formation and creating multiple transverse hydraulic fractures crossing this wellbore are essential to make unconventional reservoirs economically viable. Although the type of formation and experience with horizontal wells in a specific formation will dictate the most appropriate type of well completion to be used, a commonality is the use of simultaneous injection into multiple entry points (i.e., clusters of perforation holes made in the casing and cement) with the intent of creating multiple hydraulic fractures in each of multiple, repeated stages (see Figure 1). Typically, each stage comprises three to six perforation clusters, and each stage is repeated 20-40 times on each well. The goal of this completion technique is to generate uniform hydraulic fractures from all perforation clusters within a stage; hence, to create high conductivity pathways to the formation for oil and gas production that uniformly stimulate the reservoir rock. However, industry experience with field data analysis (i.e., production logging during which a flow sensor is moved through the well to measure the contribution of each perforation cluster to the overall production rate) and predictions from simulations make it clear that uniform stimulation can be an elusive goal. For example, Miller et al. (2011) interpreted hundreds of production logs from multiple basins, concluding that approximately two thirds of perforation clusters contribute to well production. Similarly, Molenaar et al. (2012) published one of the first studies using distributed acoustic sensing (DAS) technology with fiber optic cables in a horizontal wellbore, thereby detecting that

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“…One usually considers that increasing the perforation clusters in one stage can generate a similar number of fractures after hydraulic fracturing. However, production logging and tracer detection demonstrated that not all fractures along the horizontal wellbore can effectively propagate [11][12][13][14][15]. Fracturing fluids and proppants do not enter into each cluster evenly.…”

Section: Introductionmentioning

confidence: 99%

Numerical Study of Simultaneous Multiple Fracture Propagation in Changning Shale Gas Field

Xie¹,

Huang

Sang³

et al. 2019

Energies

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Recently, the Changning shale gas field has been one of the most outstanding shale plays in China for unconventional gas exploitation. Based on the more practical experience of hydraulic fracturing, the economic gas production from this field can be optimized and gradually improved. However, further optimization of the fracture design requires a deeper understanding of the effects of engineering parameters on simultaneous multiple fracture propagation. It can increase the effective fracture number and the well performance. In this paper, based on the Changning field data, a complex fracture propagation model was established. A series of case studies were investigated to analyze the effects of engineering parameters on simultaneous multiple fracture propagation. The fracture spacing, perforating number, injection rate, fluid viscosity and number of fractures within one stage were considered. The simulation results show that smaller fracture spacing implies stronger stress shadow effects, which significantly reduces the perforating efficiency. The perforating number is a critical parameter that has a big impact on the cluster efficiency. In addition, one cluster with a smaller perforating number can more easily generate a uniform fracture geometry. A higher injection rate is better for promoting uniform fluid volume distribution, with each cluster growing more evenly. An increasing fluid viscosity increases the variation of fluid distribution between perforation clusters, resulting in the increasing gap between the interior fracture and outer fractures. An increasing number of fractures within the stage increases the stress shadow among fractures, resulting in a larger total fracture length and a smaller average fracture width. This work provides key guidelines for improving the effectiveness of hydraulic fracture treatments.

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Perforation Cluster Efficiency of Cemented Plug and Perf Limited Entry Completions; Insights from Fiber Optics Diagnostics

Cited by 133 publications

References 10 publications

Stimulated Reservoir Volume Characterization and Optimum Lateral Well Spacing Study of Two-Well Pad: Midland Basin Case Study

Stimulated Reservoir Volume Characterization and Optimum Lateral Well Spacing Study of Two-Well Pad: Midland Basin Case Study

Laboratory Experiments Contrasting Growth of Uniformly and Nonuniformly Spaced Hydraulic Fractures

Numerical Study of Simultaneous Multiple Fracture Propagation in Changning Shale Gas Field

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