In-Situ Stress Tests and Acoustic Logs Determine Mechanical Properties and Stress Profiles in the Devonian Shales

Gatens, J.M.; Harrison, Charles W.; Lancaster, D.E.; Guidry, F.K.

doi:10.2118/18523-pa

Cited by 45 publications

(18 citation statements)

References 8 publications

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“…This mineral composition is typical for most of the Devonian shale in the US. 8 The predominant presence of the low swelling clay, illite and chlorite, in these shales sometimes misleads the choice of drilling and fracturing fluid chemistry, and in many cases nearby water sources are used. Later in this paper, the choice of drilling and fracturing fluid chemistry will be proven to be more an important factor on wellbore stability and hydraulic fracturing efficiency than previously assumed.…”

Section: Mineralogy Quantification Using Ecs Log and Xrdmentioning

confidence: 99%

Geomechanics Field and Laboratory Characterization of Woodford Shale: The Next Gas Play

Abousleiman

Tran

Hoang

et al. 2007

SPE Annual Technical Conference and Exhibition

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fax 01-972-952-9435. AbstractWoodford shale is emerging as one of the major gas formations in the US Midwest. Despite its tremendous potential, existing data on the Woodford shale geomechanics characterization are limited at best. In this work, a well in the Woodford shale formation, 200 feet deep, was cored and logged in Oklahoma, USA. The resulting retrieved preserved cores were lab tested using standard acoustic techniques and triaxial testing for shale mechanical and poromechanical characterization in terms of compressibility, strength, pore pressure coefficient, Young's modulus, Poisson's ratio, etc. In addition, shale mechanical parameters alteration when in contact with drilling muds and fracturing fluids were measured using Brazilian tests and the innovative Inclined Direct Shear Testing Device (IDSTD™). Finally, mechanical Woodford shale parameters were also measured and correlated with field log results, using samples a tiny as drill cuttings (a few millimeters in size) with the newly emerging nanoindentation rock characterization techniques developed in the GeoGenome™ Industry Consortium. This newly developed methodology for rock testing and shale chracterization, part of the nanotechnology wave, showed excellent results when compared with shale acoustic laboratory measurements and log data and results.Despite a relatively high quartz content as shown by XRD and Elemental Capture Spectroscopy (ECS) log results, the Woodford shale does exhibit clear transversely isotropic mechanical characteristics, from Young's moduli to Poisson's ratios and other mechanical parameters. Moreover, IDSTD™ and Brazilian tensile tests on the preserved Woodford samples exposed to different drilling and hydraulic fracturing fluids showed that fluid effects play an important role on both compressive strength and tensile strength of the shale despite the fact that the Woodford clay content mainly composes of illite and chlorite.The mechanical and poromechanical properties of Woodford shale were measured at four different scales, from field well logs to standard rock testing to the penny-size samples of IDSTD™ and down to drill cuttings scales using the nanoindentation. Furthermore, the innovative nano-indentation techniques for rock testing have allowed the construction of a GeoGenome TM simulation model which can estimate and determine macroscopic rock properties based on porosity, packing density, and mineralogy. The simulated moduli and parameters using this model showed excellent agreement when compared to both lab and field log results.

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Section: Mineralogy Quantification Using Ecs Log and Xrdmentioning

confidence: 99%

Geomechanics Field and Laboratory Characterization of Woodford Shale: The Next Gas Play

Abousleiman

Tran

Hoang

et al. 2007

SPE Annual Technical Conference and Exhibition

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“…The preferred method for estimating the horizontal stresses is to use a strain-corrected log-based approach [5][6][7][8][9][10] in which the horizontal strain is kept constant. The method utilizes measured horizontal stress data from microfrac or LOT's in combination with RMP's, pore pressure and temperature, to calculate a "tectonic" strain.…”

Section: Methodsmentioning

confidence: 99%

Log-Based Pore Volume Compressibility Prediction-A Deepwater GoM Case Study

Wolfe¹,

Russell²,

Luise³

et al. 2005

Proceedings of SPE Annual Technical Conference and Exhibition

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TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractPore Volume Compressibility (PVC) is one of the most important parameters for proceeding with project sanctioning. An accurate estimation of pore volume compressibility of reservoir rocks is essential for compaction evaluation, reservoir drive determination, reserves estimates, reservoir pressure maintenance, casing collapse analyses, and production forecasting. This information is then used in modeling the reservoir and calculating the economic value of the project. Thus, obtaining credible indications of this value early in the well evaluation process is invaluable. Unfortunately, this data is usually required long before a conventional core can be obtained and mechanical rock properties measured. Furthermore, cores are only available at discrete points along the wellbore requiring the data to be extrapolated to the missing sections.To accommodate the need for this data early in the project and to circumvent the short comings of core-based information gaps in the wellbore, a cost effective approach that utilizes common wireline data is used to obtain a continuous profile of the pore volume compressibility with depth shortly after wireline logging operations have concluded. The method employs a log-based mechanical property program that simulates triaxial loading to obtain static elastic moduli as well as rock strength. The resulting rock mechanical properties are then converted into their uniaxial strain equivalents and used to determine the pore volume compressibility. The process is repeated for several drawdown stages with the condition that the deformations are contained within elastic limits. This yields the complete reservoir compaction trend as a function of reservoir depletion.The log-based model was recently validated by comparing with lab-derived results from an offset well in deepwater Gulf of Mexico. The results indicate that the uniaxial pore volume compressibility obtained from the log-based method matches well with the results obtained in the laboratory. This fact suggests that the log-based approach should be utilized with a high degree of confidence to determine the PVC in the absence of core data, insufficient depth coverage of the cores, and/or to validate the core results.

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“…7 We were successful in transferring this technology to the Berea and developing a log-based stress profile. The in-situ stresses determined from the open-and cased-hole tests were essentially identical, with similar stresses also determined in the upper and lower Berea.…”

Section: Stress Profilementioning

confidence: 99%

Reservoir and Stimulation Evaluation of the Berea Sandstone Formation in Pike County, Kentucky

Frantz¹,

Hopkins²,

Lancaster³

et al. 1993

Low Permeability Reservoirs Symposium

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The Gas Research Institute (GRI) has been sponsoring a three-well cooperative program with Ashland Exploration, Inc. (AEI) during the past two years evaluating the Devonian Shale and Berea sandstone formations in Pike County of eastern Kentucky. The COOP 2 was targeted to evaluate the Berea and was GRrs fJrSt comprehensive tight gas sand research project in the Appalachian Basin. The objective of the research was to use and apply technologies developed previously in otherGRI research. This paper will summarize the integrated reservoir and hydraulic fracture descriptions determined from analyzing the data collected in this project. The results presented can be applied by operators to better understand the productive mechanisms in the Berea reservoir, to predict well performance, and to design completion procedures and stimulation treatments. The methodology can also be applied to other tight gas sand formations.

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In-Situ Stress Tests and Acoustic Logs Determine Mechanical Properties and Stress Profiles in the Devonian Shales

Cited by 45 publications

References 8 publications

Geomechanics Field and Laboratory Characterization of Woodford Shale: The Next Gas Play

Geomechanics Field and Laboratory Characterization of Woodford Shale: The Next Gas Play

Log-Based Pore Volume Compressibility Prediction-A Deepwater GoM Case Study

Reservoir and Stimulation Evaluation of the Berea Sandstone Formation in Pike County, Kentucky

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