Quantitative Properties From Drill Cuttings To Improve the Design of Hydraulic-Fracturing Jobs in Horizontal Wells

Ortega, Camilo; Aguilera, Roberto

doi:10.2118/155746-pa

Cited by 11 publications

(5 citation statements)

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“…Logs can show lithological composition and variation which can determine the areas that may be less successful at producing (Barree et al 2014). Drill cuttings can help in reservoir characterization but aren't continuous for an entire well (Ortega & Aguilera 2014). While these methods can be indicative of areas in which selective stimulation could prove beneficial, the costs associated with such procedures could limit the amount of data collected.…”

Section: Application To Selective Stimulationmentioning

confidence: 99%

Evaluating Multiple Methods to Determine Porosity from Drilling Data

Cedola

Atashnezhad

Hareland

2017

SPE Oklahoma City Oil and Gas Symposium

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Porosity can be obtained from drilling data by using different correlations that relate the porosity to the unconfined compressive strength (UCS), which is obtained from drill bit inverted rate of penetration (ROP) models. Knowing the porosity at a given depth can benefit in helping to define the formations being penetrated and to characterize variations in a reservoir, thereby benefitting in selective stimulation. In this paper, previous studies that present methods for calculating porosity from UCS values will be compared and evaluated with sections of porosity that have been calculated from log data taken from three wells in Alberta, Canada. The correlations that will be compared include: Onyia, Sarda, Erfourth, and the UCS-gamma ray methods. The Onyia, Sarda, and Erfourth correlations are previously published while the UCS-gamma ray method correlates UCS in conjunction with the gamma ray at the bit. The porosity values that are found through these correlations are then plotted and their trends compared to each other as well as to the porosity obtained from log data in different sections from the well in Alberta, Canada. This process will help to determine what formation types are best correlated to the individual correlation. Typical drilling data is used in an inverted ROP model to obtain UCS. The UCS and gamma ray values are then taken and related to the porosity through the correlations presented in this paper and compared to the porosity determined from log data. Examining the different correlations that have been analyzed in various types of formations yield information indicating which correlation is best correlated to a specific formation type. The comparison's show that the predictability for some correlations are reasonable for limited datasets and sections of the well. To reasonably predict porosity values for mixed lithologies or shale formations, the integration of gamma log data is necessary. The trends exhibited from the correlations show that the comparison between porosity in shale is better seen when using the integrated UCS-gamma ray correlation. Utilizing the new UCSgamma ray model seemingly indicates that this useful new method can more accurately predict porosity variations in mixed lithologies and in shale reservoir sections. Bettering stimulation placement as well as minimizing logging in the reservoir can greatly reduce the overall cost of the operation. The improved selective stimulation process could also allow for higher production rates and/or potential reduced stimulation cost, thus increasing overall profit. This template is provided to give authors a basic shell for preparing your manuscript for submittal to an SPE meeting or event. Styles have been included to give you a basic idea of how your finalized paper will look before it is published by SPE. All manuscripts submitted to SPE will be extracted from this template and tagged into an XML format; SPE's standardized styles and fonts will be used when laying out the final manuscript. Links will be added to your manuscript for r...

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Section: Application To Selective Stimulationmentioning

confidence: 99%

Evaluating Multiple Methods to Determine Porosity from Drilling Data

Cedola

Atashnezhad

Hareland

2017

SPE Oklahoma City Oil and Gas Symposium

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“…A method for the quantitative determination of porosity, permeability, and rockmechanics properties from drill cuttings of at least 1 mm has been proposed [178]. The porosity value is used for determining a brittleness index by implementing the sonic-derived porosity theory and a dipole sonic log from an offset well.…”

Section: Horizontal Wellsmentioning

confidence: 99%

“…This parameter is called frac value and in conjunction with the brittleness index and permeability constitutes the main result of the methodology: the cut log [178]. This parameter is called frac value and in conjunction with the brittleness index and permeability constitutes the main result of the methodology: the cut log [178].…”

Section: Horizontal Wellsmentioning

confidence: 99%

“…The method allows an improved design of multistage hydraulic fracturing jobs in horizontal wells [178]. This provides additional information to stimulation designers for deciding where to initiate hydraulic fractures and how to optimize fracture spacing and fracture size per stage instead of considering a homogeneous reservoir volume throughout the whole lateral section.…”

Section: Horizontal Wellsmentioning

confidence: 99%

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Fracturing fluids

2015

Petroleum Engineer's Guide to Oil Field Chemicals and Fluids

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Hydraulic fracturing is a technique to stimulate the productivity of a well. A hydraulic fracture is a superimposed structure that remains undisturbed outside the fracture. Thus the effective permeability of a reservoir remains unchanged by this process. The increased productivity results from the increased wellbore radius, because in the course of hydraulic fracturing, a large contact surface between the well and the reservoir is created.The literature from 2004 to 2014, more than 100 references concerning waterbased fracturing fluids for fracturing ultralow-to moderate-permeability reservoirs has been reviewed [1].Guar-based polymers are still used in fracturing at temperatures less than 150 • C. To minimize the damage associated with this class of polymers, several approaches are known. These include the use of a lower polymer concentration in formulating these fluids and the use of different crosslinking agents. Higher viscosities with lower polymer loadings can be achieved. In addition, cleaner guar-based polymers are used now, because commercial guar contains some 5% of residues, which may cause a damage of proppant packs.It has been found that shear and pressure effects on the rheological behavior of borate crosslinked gels are important. Although these fluids recover their viscosity after shear, they have been observed to lose a significant portion of their viscosity under high pressures.When fracturing is done in deeper wells, i.e., in hotter reservoirs, a new class of thermally stable polymers became relevant. These are poly(acrylamide)-based polymers. These synthetic polymers show a sufficient viscosity at temperatures up to 230 • C [1]. Examples are 2-acrylamido-2-methylpropanesulfonic acid and copolymers of partially hydrolyzed acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, and vinyl phosphonate. High-density brines have been used to increase the hydrostatic pressure by 30% for high-pressure pumping.Also, new breaker materials emerged [1]. These breakers destroy the gel by a reaction with the crosslinking agent. They form ligands with the metallic crosslinking agents and displace them from the crosslinking moieties of the guar-based polymers. Examples of these breakers include poly(succinimide) derivates and lignosulfonate derivates.To minimize the environmental impact of using massive amounts of fresh water and to minimize costs associated with treating produced water, the use of produced water in hydraulic fracturing treatments has been reported. Petroleum Engineer's Guide to Oil Field Chemicals and Fluids. http://dx.567 568 CHAPTER 17 Fracturing fluids B HO 17.3 Types of hydraulic fracturing fluids 571 TYPES OF HYDRAULIC FRACTURING FLUIDSGenerally, a hydraulic fracturing treatment involves pumping a proppant-free viscous fluid, or pad, usually water with some fluid additives to generate high viscosity, into a well faster than the fluid can escape into the formation so that the pressure rises and the rock breaks, creating artificial fractures or enlarging existing fractures.After fracturing...

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“…Emsley et al 2007;Slightam 2012), core analysis (e.g. Bosworth et al 2012;Sonntag et al 2012;Sagi et al 2013) and drill cuttings (Ortega & Aguilera 2014). Geologically appropriate outcrop analogues are also frequently studied as proxies for subsurface fracture networks (e.g.…”

Section: Characterizing Fracture Networkmentioning

confidence: 99%

Advances in the study of naturally fractured hydrocarbon reservoirs: a broad integrated interdisciplinary applied topic

Spence

Couples

Bevan

et al. 2014

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Naturally fractured reservoirs, within which porosity, permeability pathways and/or impermeable barriers formed by the fracture network interact with those of the host rock matrix to influence fluid flow and storage, can occur in sedimentary, igneous and metamorphic rocks. These reservoirs constitute a substantial percentage of remaining hydrocarbon resources; they create exploration targets in otherwise impermeable rocks, including under-explored crystalline basement, and they can be used as geological stores for anthropogenic carbon dioxide. Their complex fluid flow behaviour during production has traditionally proved difficult to predict, causing a large degree of uncertainty in reservoir development. The applied study of naturally fractured reservoirs seeks to constrain this uncertainty and maximize production by developing new understanding, and is necessarily a broad, integrated, interdisciplinary topic. Some of the methods, challenges and advances in characterizing the interplay of rock matrix and fracture networks relevant to fluid flow and hydrocarbon recovery are reviewed and discussed via the contributions in this volume.Global estimates of conventional hydrocarbon resources are typically subdivided based on lithological reservoir types for example, carbonate or siliciclastic (e.g. Roehl & Choquette 1985). However, many of these sedimentary rock reservoirs may contain fractures to a greater or lesser degree. The recent boom of unconventional reservoirs highlights once again the key role that natural fractures can play in helping production of fluids. It also requires an improved understanding of the geology and physics of natural fracture networks to meet public expectations regarding safety issues. Moreover, fracture networks can be present in otherwise impermeable crystalline basement rocks (e.g. Sanders et al. 2003;Murray & Montgomery 2012;Slightam 2012) and igneous intrusions (e.g. Gudmundsson & Løtveit 2012), also allowing these rocks to form potential fractured reservoirs. Historically, fractured crystalline basement rocks have been under-explored as potential hydrocarbon reservoirs. Naturally fractured reservoirs constitute a substantial percentage of remaining hydrocarbon resources. Naturally fractured reservoirsA reservoir fracture is a general term used to describe a 'naturally occurring macroscopic planar discontinuity in rock due to deformation, or physical diagenesis' (Nelson 2001). Reservoir fractures encompass both extensional ( joints) and shear (faults) structures. Fractures formed by brittle tectonic deformation are the most common focus for studies of naturally fractured reservoirs. However, reservoir fractures may also include structures that formed by desiccation (e.g. shrinkage cracks) and syneresis (e.g. chickenwire texture) in sediments, and structures that formed by thermal , as used here. Naturally fractured reservoirs are generally defined as such when the fracture network has a significant influence on fluid flow in the reservoir such that: (1) the fracture networ...

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Quantitative Properties From Drill Cuttings To Improve the Design of Hydraulic-Fracturing Jobs in Horizontal Wells

Cited by 11 publications

References 4 publications

Evaluating Multiple Methods to Determine Porosity from Drilling Data

Evaluating Multiple Methods to Determine Porosity from Drilling Data

Fracturing fluids

Advances in the study of naturally fractured hydrocarbon reservoirs: a broad integrated interdisciplinary applied topic

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