Understanding Chemical-Potential-Related Transient Pore-Pressure Response To Improve Real-Time Borehole (In)Stability Predictions

Understanding Chemical-Potential-Related Transient Pore-Pressure Response To Improve Real-Time Borehole (In)Stability Predictions Uday A. Tare; Uday A. Tare Halliburton Energy Services Search for other works by this author on: This Site Google Scholar Fersheed K. Mody; Fersheed K. Mody Halliburton Energy Services Search for other works by this author on: This Site Google Scholar Ali I. Mese Ali I. Mese Halliburton Energy Services Search for other works by this author on: This Site Google Scholar Paper presented at the SPE/CIM International Conference on Horizontal Well Technology, Calgary, Alberta, Canada, November 2000. Paper Number: SPE-65514-MS https://doi.org/10.2118/65514-MS Published: November 06 2000 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Tare, Uday A., Mody, Fersheed K., and Ali I. Mese. "Understanding Chemical-Potential-Related Transient Pore-Pressure Response To Improve Real-Time Borehole (In)Stability Predictions." Paper presented at the SPE/CIM International Conference on Horizontal Well Technology, Calgary, Alberta, Canada, November 2000. doi: https://doi.org/10.2118/65514-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE/CIM International Conference on Horizontal Well Technology Search Advanced Search AbstractChemical potential related borehole (in)stabilities in the field are predominantly time-dependent. With the intention of developing a real-time wellbore (in)stability modeling capability, experimental work has been undertaken to investigate the role of chemical potential of drilling fluids on transient pore pressure and time-dependent rock property alterations of shale formations. The current work presents the concept and discusses the results of these undertakings.The experiments using a Pore Pressure Transmission Test (PPT) apparatus expose formation (shale) cores under simulated downhole conditions to various salt solutions and drilling fluids. The uniqueness of this study comes from the fact that time-dependent alterations in the pore pressure, acoustic, static properties and strength of formations subjected to compressive tri-axial stress are recorded during the PPT experiments. This eliminates the anisotropy-associated differences obtained when different samples are used to determine the relationship between these characteristic parameters of shale formations. This comprehensive testing program will enhance our understanding of the relationship between acoustical, mechanical and chemical properties of shale as a function of time when exposed to a drilling fluid.The main objective of this effort is to translate the results of the PPT tests to actual drilling conditions. Wherein the formation-drilling fluid chemical potential model would be validated and updated in real-time to predict borehole (in)stabilities.IntroductionShales make up over 75 percent of drilled formations and causes over 90 percent of wellbore instability problems. The drilling of shale can result in a variety of problems ranging from washout to complete collapse of hole. More typically, drilling problems in shales are experienced as bit balling, sloughing, or creep. (In)stability in shales is a continuing problem that results in substantial annual expenditure by the petroleum industry — $700 million according to conservative estimates. With the cost of drilling increasing, the need to drill extended-reach wells with long open hole intervals has also increased. In the past, oil-based muds (OBM) have been the system of choice for difficult drilling. Their application has been typically justified on the basis of borehole stability, thermal stability, fluid loss, lubricity, etc. As environmental concerns restrict the use of oil-based muds, the petroleum-service industry must provide innovative means to obtain OBM performance without negatively impacting the environment. Water-based muds (WBM) are attractive replacements from a direct cost viewpoint. But, conventional WBM systems have failed to meet key performance measures met with OBMs, especially while drilling high-angle, extended-reach well trajectories going through water-sensitive shale formations.Past efforts to develop improved WBM for shale drilling have been hampered by a limited understanding of the drilling fluid/shale interaction phenomenon. This limited understanding has resulted in drilling fluids designed with inadequately optimized properties that are required to prevent the onset of borehole instability problems. Historically, wellbore (in)stability problems have been approached on a trial-and-error basis, going through a costly multiwell learning curve before arriving at reasonable solutions for optimized operations and systems. Recent studies1,2 of fluid-shale interactions have produced fresh insights into the underlying causes of borehole (in)stability, and these studies suggest new and innovative approaches as to the design of water-based drilling fluids. Keywords: membrane efficiency, wellbore integrity, stability, shale, drilling fluids and materials, wellbore design, spe ps-cim 65514, borehole, application, chemical-potential-related transient pore-pressure response Subjects: Wellbore Design, Drilling Fluids and Materials, Reservoir Characterization, Wellbore integrity, Drilling fluid management & disposal This content is only available via PDF. 2000. SPE/PS-CIM International Conference on Horizontal Well Technology You can access this article if you purchase or spend a download.

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