Understanding Complex Source Rock Petroleum Systems to Achieve Success in Shale Developments

Dusterhoft, Ron; Williams, Ken; Kumar, Amit; Croy, Matt

doi:10.2118/164271-ms

Cited by 18 publications

(2 citation statements)

References 12 publications

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“…At this stage, this model can be quite coarse because of scarce or sparse data; however, it is still the most comprehensive concentration of information available in addition to a collaboration hub to help direct the key decisions mentioned previously. Dusterhoft et al [10] provide an outline of a basic procedure that has been summarized in Figs. (2a-c).…”

Section: The Use Of Earth Modeling In Shale Assetsmentioning

confidence: 99%

Shale Reservoir-Centric Completions

Spaid¹,

Dahl²,

Dusterhoft³

et al. 2016

TOPEJ

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In North America, the transition from more conventional reservoirs into tight, basin-centered gas and now source shales has caused the industry to change the way reservoir performance is being assessed, measured, and documented. Historically in conventional reservoirs the reservoir quality was carefully examined on a well by well basis to determine reserves in place and exploitation plans. For unconventional reservoirs, however, the commercializing of such plays quickly became centered on horizontal drilling of long laterals combined with massive volume, high rate multi-stage hydraulic fracturing. In that environment, completion design and hydraulic fracturing have become more of a statistical process; additionally, incremental improvement and innovation are used to create a treatment schedule often replicated across an entire field without consideration of reservoir variability across a lateral. Based upon vertical well experience, the fracture initiation points can be carefully selected by identifying the locations within the well that are best to perforate. In a horizontal well, however, the location of the lateral defines the fracture initiation points anywhere along the well, so the stratigraphic location of the well lateral becomes critical in non-homogeneous shale plays. To address this, engineers and geoscientists can identify important parameters necessary for optimum completion design, and earth modelling can then be used as a tool to capture and model these properties across the asset making critical information available as needed for drilling, completion, and production operations.

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Section: The Use Of Earth Modeling In Shale Assetsmentioning

confidence: 99%

Shale Reservoir-Centric Completions

Spaid¹,

Dahl²,

Dusterhoft³

et al. 2016

TOPEJ

View full text Add to dashboard Cite

show abstract

“…This includes basin and source rock modeling, core analysis, geochemistry, petrophysical analysis, geologic modeling, and geophysics, followed by geostatistical earth modeling for creating the most realistic subsurface model possible. Dusterhoft et al (2013) provided a relatively detailed description of this process, which resulted in the creation of a detailed geocellular subsurface model. A key factor to consider is that this is only the first generation model; as the project progresses, this becomes the platform for capturing all present and future wellbore, drilling, formation evaluation, stimulation, production, and reservoir information.…”

Section: Reservoir Characterizationmentioning

confidence: 99%

Accelerating Shale Asset Success Through Applied Reservoir Understanding

Dusterhoft

Dahl²,

Spaid³

et al. 2014

Proceedings of the 2nd Unconventional Resources Technology Conference

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Horizontal drilling and multistage hydraulic fracturing have been credited for much of the success achieved in ultralow permeability shale reservoirs, making it possible to produce natural gas, natural gas liquids, and crude oil at economic rates. Although thousands of wells have been drilled and completed using these techniques, there are relatively few design tools and processes available within the industry designed specifically for these applications. In the past, much of the optimization process has been the result of trial and error techniques that can be both costly and time consuming. This paper examines a step-out development project where new processes and tools were used to accelerate the de-risking of the asset area by identifying the best quality reservoir targets and significantly improving production and economics by implementing a completion optimization process. This reservoir centric process uses earth modeling, complex fracture modeling, and reservoir simulation tools developed specifically for shale type formations. It also focuses on designing the wellbores to best accommodate the staged stimulation treatments that can help maximize the stimulated volume and the connected fracture area within this volume. When optimized, this process can help maximize the estimated ultimate recovery (EUR) while sustaining economically viable production rates. A detailed example is presented illustrating how these tools were successfully applied within a new development to accelerate reservoir understanding, help improve well performance consistency through more effective well placement, and significantly increase well performance through applied engineering processes, completion designs, and effective stimulation treatments. The success of the project is discussed to illustrate both the initial and sequential performance improvements as new processes and designs were implemented. Total well cost comparisons are also included to verify the economic benefit achieved within this asset.

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