Hydraulic Fracture Design and Well Production Results in the Eagle Ford Shale: One Operator's Perspective

Bazan, Lucas W.; Lattibeaudiere, Michael G.; Palisch, Terry

doi:10.2118/155779-ms

Cited by 17 publications

(11 citation statements)

References 15 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Therefore the conclusions from this set of simulations validate and confirm the best practice of injecting the smallest proppant first. Palisch et al (2012) confirms that most treatments inject the smallest proppant first, but some operators do start their slickwater treatment with 20/40 mesh sand under the assumption that proppant bed fluidization is the main transport mechanism in slickwater jobs, and that the first injected proppant will settles close to the perforation. The simulation results in Figure 27, Figure 28 and Figure 29 do not support this strategy, but it should be further investigated with the appropriate pumping schedule.…”

Section: Proppant Injection Sequencementioning

confidence: 61%

“…Zou et al (2012) presented a similar workflow using instead a semianalytical model for the production simulation. Bazan et al (2012) published an parametric study based on a workflow that provides economics optimum, using a wiremesh type of fracturing model to capture the complexity of hydraulic fracture networks. The objective of this paper is to present a parametric study on the relation between the parameters of a treatment design and the production outcome based on numerical simulation.…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Analysis on the Impact of Fracturing Treatment Design and Reservoir Properties on Production from Shale Gas Reservoirs

et al. 2013

View full text Add to dashboard Cite

Production from shale gas reservoirs depends greatly on the efficiency of hydraulic fracturing treatments. The cumulated experience in the industry has led to several best practices in treatment design, which have improved productivity of these reservoirs. However, further advancement of treatment design requires a deeper understanding of the complex physics involved in both hydraulic fracturing and production, such as stress shadow, proppant placement and treatment interaction with pre-existing natural fractures. This paper sheds light on the non-linear physics involved in the production of shale gas reservoirs by improving the understanding of the complex relation between gas production, the reservoir properties, and several treatment design parameters. A fracturing-to-production simulation workflow integrating the Unconventional Fracture Model (Weng et al., 2011), with the Unconventional Production Model (Cohen et al., 2012) is presented. By applying this workflow to a realistic reservoir, we did an extensive parametric study to investigate the relation between production and treatment design parameters such as fracturing fluid viscosity, proppant size, proppant concentration, proppant injection order, treatment volume, pumping rate, pad size and hybrid treatment. The paper also evaluates the influence of unconventional reservoir properties -such as permeability, horizontal stress, horizontal stress anisotropy, horizontal stress orientation, Poisson's ratio and Young's modulus -on production. Since this paper focuses on fluid and proppant selection, our methodology was to run 28 simulations to cover the 2D parametric space of proppant size and fracturing fluid viscosity for all of these parameters. More than fourteen hundred simulations were run in this parametric study and the results provide guidelines for optimized treatment design. This paper illustrates how this unique workflow can identifies the optimum fluid and proppant selection that gives the maximum production for a given reservoir and completion. In addition, the parametric study shows how these optimums evolve as a function of reservoir and treatment parameters. The results validate several best practices in treatment design for shale. For example, combination of different sizes of proppant optimizes production by maximizing initial production and slowing down production decline. Simulations also confirm the best practice of injecting the smallest proppant first. The study explains why slickwater treatments should be injected at maximum pumping rate and preferably with 40/70 mesh sand. It also illustrates why reservoirs with high Young's modulus (such as the Barnett shale) can be stimulated effectively with slickwater. Another key finding is that the optimum fluid viscosity increases with treatment volume.

show abstract

Section: Proppant Injection Sequencementioning

confidence: 61%

Section: Introductionmentioning

confidence: 99%

Analysis on the Impact of Fracturing Treatment Design and Reservoir Properties on Production from Shale Gas Reservoirs

et al. 2013

View full text Add to dashboard Cite

show abstract

“…The Eagle Ford is composed of organic-rich calcareous mudstones and marls with thickness ranging from 50 to 350 feet (Bazan et al, 2012). Its composition can be defined roughly as 55% calcite, 20% quartz, 15% clay, and 10% kerogen.…”

Section: Eagle Ford Shale Backgroundmentioning

confidence: 99%

Coupled Geomechanics and Fluid Flow Model for Production Optimization in Naturally Fractured Shale Reservoirs

Curnow

Tutuncu

2015

SEG Technical Program Expanded Abstracts 2015

View full text Add to dashboard Cite

The benefits of hydraulic fracturing horizontal wells in unconventional reservoirs for production enhancement are evident; however, the best methods to truly increase recovery efficiency through these stimulations are still under great examination.Analogous to how operators and service companies discovered that Barnett-style slickwater treatments were not successful in all reservoirs, companies are beginning to recognize the importance of engineered stimulations, specifically in regard to geomechanics. Rather than perforating for only production purposes, hydraulic fracturing design has now turned its focus to perforating for reservoir rock stimulation.Enhanced fracture network complexity through induced fractures greatly increases the contact area and reservoir drainage for maximum productivity. However, to accomplish the stimulation of both primary and secondary fracture networks, the coupled behaviors of geomechanics and fluid flow in response to the hydraulic fracturing operations must be considered.This research details the development of a coupled geomechanics and fluid flow model for the purpose of hydraulic fracture design optimization through the evaluation of different stimulation patterns. The patterns under consideration include the Zipper, Texas Two-Step, and Modified Zipper designs. Furthermore within these patterns, the well locations and hydraulic fracture properties are analyzed to determine the most ideal design for a shale oil reservoir based on recovery efficiency and economic viability.

show abstract

“…This is critical to the success of an Appraisal Programme, there are numerous examples (Bazan, 2012), within North America, of fracture design/approach changing from X-Link (cross-linked gel), down through hybrid(s) all the way to the HRWF/Slickwater (High-Rate Water-Frac) style; and then back again. The success or failure of such selected fracture types are dependent on the variation of rock properties, primarily the permeability, the in-situ stress state and any rock-fabric influence (e.g.…”

Section: Technology Selectionmentioning

confidence: 99%

Optimising Remote Unconventional Gas Exploration

Rylance

2013

All Days

View full text Add to dashboard Cite

Exploration and Appraisal of Unconventional gas, in remote areas, brings with it a variety of challenges; which are not normally encountered in established development areas such as North America. These challenges include, higher cost(s), logistical issues, lack of existing infra-structure, limited well numbers to name but a few. This paper will describe some of the important considerations, technology choices and approaches that can be considered in order to optimise such a remote Exploration and Appraisal programme.There are a number of considerations, selections, choices and decisions to be made for an Exploration and Appraisal programme, which can significantly affect the results and outcome when performed in a remote environment. For example, vertical vs. horizontal wells, lower completion technology, stimulation approaches and data gathering choices. Due to a number of unique conditions in remote locations, the optimum decisions are not always obvious, nor always reflect typical practices in established areas and this paper will describe the rationale behind this and the appropriate considerations for various Drilling and Completion aspects.The author will describe, options, considerations and decision making processes based on experience from recent case histories from a number of world-wide Exploration and Appraisal operations in unconventional gas. The paper will attempt to indicate the relative importance and value associated with these decisions and their impact on the potential success of an Exploration and Appraisal programme.Unconventional gas Exploration and Appraisal programmes can be challenging to progress in established areas; and this can be compounded by several orders of magnitude when operating in a remote environment. The requirements for establishing unconventional resource assessment can be somewhat different to conventional approaches and an Appraisal programme should take this into account. This paper summarises a number of key lessons learned from a worldwide selection of Unconventional operations and distils them into a philosophy that promotes and encourages success. SPE 163987Exploration, Appraisal and Development Long before any Development actually proceeds, the Exploration and Appraisal phase(s) are performed, and it is of course the objectives, deliverables and results of these phases that will be critical in determining whether or not a Development actually proceeds. For the Development of conventional oil and gas, the Exploration phase may consist of as little as one or two wells, depending upon and definition of, the large-scale heterogeneity; confirming the trap, the reservoir conditions and the presence of hydrocarbons. Appraisal is then utilised to perform delineation, confirmation of the resource magnitude and demonstration of single well deliverability prior to the Development phase.Unconventional oil and gas however is a different matter, in part due to small scale heterogeneity, production rate variance and hence the statistical nature of a play. With such resources t...

show abstract

Hydraulic Fracture Design and Well Production Results in the Eagle Ford Shale: One Operator's Perspective

Cited by 17 publications

References 15 publications

Analysis on the Impact of Fracturing Treatment Design and Reservoir Properties on Production from Shale Gas Reservoirs

Analysis on the Impact of Fracturing Treatment Design and Reservoir Properties on Production from Shale Gas Reservoirs

Coupled Geomechanics and Fluid Flow Model for Production Optimization in Naturally Fractured Shale Reservoirs

Optimising Remote Unconventional Gas Exploration

Contact Info

Product

Resources

About