Abstract Even in routine applications, the safety, economic and technical problems associated with lost circulation can severely impact drilling operations. The negative consequences are magnified greatly in the deepwater environment. Dramatic reduction in penetration rate and the downtime spent regaining circulation can further escalate already high operating costs. More importantly, the well control issues surrounding lost circulation pose critical safety concerns. In many of these wells, merely identifying the thief zone or zones is a major technical challenge. Furthermore, once identified, the vugs and fractures in the loss zones are at times too large to be bridged with conventional lost circulation material. This paper describes the development of a uniquely engineered lost circulation pill that when used in tandem with new real-time geomechanical analysis methods and pill formulation software, cured severe losses in the deepwater Gulf of Mexico. The authors will describe the development and laboratory modeling used in producing the specialized and chemically activated cross-linked pills, engineered to stop whole drilling fluid losses. As detailed in the paper, the pill proved to be far superior to conventional lost circulation material. Further, the paper will discuss its application in a well drilled in more than 2,800 ft of water in the Gulf of Mexico, which had encountered losses of up to 2,000 bbl of synthetic-base drilling fluid. The 100-bbl pill was formulated using a specialized software package. This was used in combination with a new process for analyzing the location, and extension pressure of the drilling induced hydraulic fracture using resistivity and annular pressure measurements. Once the pill was placed across the fracture zones, squeezed and later drilled out, normal drilling resumed with pre-fracture parameters resulting in penetration rates in excess of 50 ft/hr with no further losses. In addition to discussing the development and application, the authors will outline the lessons learned on the deepwater project featuring pre-planning issues geared toward ensuring circulation is maintained throughout the wellbore.
Optimized perforation tunnel geometry, density and orientation to control sand production Jincai Zhang; Jincai Zhang Knowledge Systems Search for other works by this author on: This Site Google Scholar William Bradley Standifird; William Bradley Standifird Knowledge Systems Search for other works by this author on: This Site Google Scholar Xinpu Shen Xinpu Shen Knowledge Systems Search for other works by this author on: This Site Google Scholar Paper presented at the European Formation Damage Conference, Scheveningen, The Netherlands, May 2007. Paper Number: SPE-107785-MS https://doi.org/10.2118/107785-MS Published: May 30 2007 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Zhang, Jincai, Standifird, William Bradley, and Xinpu Shen. "Optimized perforation tunnel geometry, density and orientation to control sand production." Paper presented at the European Formation Damage Conference, Scheveningen, The Netherlands, May 2007. doi: https://doi.org/10.2118/107785-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 European Formation Damage Conference and Exhibition Search Advanced Search AbstractDestabilization of completed sandstone reservoirs reduces production rates and degrades production equipment. A major cause of such destabilization is perforation tunnel failure, which causes sand production.Classic mechanically-based sand control techniques are effective, but potentially unnecessary for some reservoirs. Modeling the occurrence and severity of sand production should help identify the most economical pairing of sand control remediation methods with the desired production rate.This paper examines an advanced technique for modeling such failures, leading to improved drilling and completion practices. In this study, 3D poro-elastoplastic Finite Element Methods (FEMs) are employed to model perforation tunnel stability. Wellbore geometry, reservoir properties, draw-down rate and perforation properties such as tunnel size, spacing and orientation are addressed, with particular attention focused on the transient phenomena near perforations, including stress re-distribution and failure development for different perforations.The results show that stability of the wellbore and perforation tunnel strongly depends upon drilling and perforation directions and perforation shot density. The relationships of the bottomhole flowing pressure, drawdown, perforation orientation, rock strength and in-situ stresses are given to provide optimal perforation for mitigating sand production.IntroductionSand production is an important issue affecting well production and casing stability. The major cause of sand production is wellbore instability and perforation tunnel failure in poorly- and un-consolidated formations. Classical sand control techniques are primarily based on installing gravel packing, frac-and-pack, etc., which dramatically increases the completion cost and reduces production. It is desirable to predict perforation tunnel stability and sanding potential before one makes a decision on whether or not to perform these costly sand control procedures.Sand production usually takes place in unconsolidated porous formations. To be effective, sanding prediction models need to address anisotropic and heterogeneous rock properties while accommodating the transient properties of the stress and fluid pressure fields around the borehole and perforation tunnels during production. In this study, a poro-elastoplastic analytical solution and 3D FEM are employed to model these complex properties. This advanced method allows modeling the anisotropy and heterogeneity of rock properties, in-situ stress, fluid pressure fields around the borehole and perforations arising from the changes that occur during reservoir depletion.The theoretical solutions are subjected to sensitivity analysis and model validation by examining a gas field in the Northern Adriatic Sea. The validated model can then be applied to design, drilling and completion operations in sand-prone reservoirs.Sanding Prediction MethodsSanding prediction is generally based on the following three categories 1,2: sand arch stability, open hole wellbore stability and perforation tunnel stability.Sand Arch StabilityLab experiments show that a sand arch is formed when sand is produced. The arch serves to support a load by resolving the vertical stress into horizontal stress. When the arch fails, the sand production begins. Figure 1 represents a sand arch failure causing sand production 3.Assuming an idealized production cavity and full spherical symmetry of the stress field, the following sand arch stability criterion was derived 4,5:Equation (1)where UCS is the uniaxial/unconfined compressive strength of the formation, q is the flow rate of the cavity, k is the formation permeability, r1 is the cavity radius and µ is the fluid viscosity. Keywords: Completion Installation and Operations, critical bottomhole, Modeling & Simulation, orientation, Artificial Intelligence, drawdown, sand production, Redistribution, horizontal stress, geometry Subjects: Perforating, Completion Installation and Operations, Completion Operations This content is only available via PDF. 2007. Society of Petroleum Engineers You can access this article if you purchase or spend a download.
A brief review is presented for patents in the technical domain of numerical analysis on mechanical behavior of formations of unconventional oil and gas. Three technologies of threedimensional (3D) numerical modeling with Abaqus for geomechanics problems existing in petroleum engineering have been critically reviewed. Case 1 is the 3D numerical calculation of mud-weight windows (MWWs). In this work, an integrated 3D method is used, which combines a one-dimensional (1D) analytical tool with the 3D Abaqus finite element (FE) tool. Case 2 is a 3D method for the optimized design of a stage interval of multi-stage hydraulic fracturing, as well as the optimized design of well spacing for horizontal wells of unconventional oil and gas resources. The so-called “real 3D” means that not only the fracture propagation in the vertical and transverse directions, but also the fracture propagation in the lateral direction, will be calculated. This makes the analysis of fracture propagation a full 3D analysis. Continuum damage mechanics (CDM) is used to investigate the development of crack clouds instead of a single crack. Case 3 provides a numerical investigation into sanding prediction for both openhole and cased hole completion forms. Dual-stress-concentration and interpretation on the total amount of plastic strain are analyzed for sanding prediction with the cased hole completion form. These three cases present technology that was disclosed in recently filed patent applications. A discussion of perspective on further development of techniques under this topic is presented at the end of the paper. Keywords: Finite element method, geomechanics, hydraulic fracturing, mud-weight window, numerical modeling, optimization, petroleum engineering, sanding prediction.
Real Time Basin Modeling: Improving Geopressure and Earth Stress Predictions William Bradley Standifird; William Bradley Standifird Knowledge Systems, Inc. Search for other works by this author on: This Site Google Scholar Martin David Matthews Martin David Matthews Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Offshore Europe Oil and Gas Exhibition and Conference, Aberdeen, United Kingdom, September 2005. Paper Number: SPE-96464-MS https://doi.org/10.2118/96464-MS Published: September 06 2005 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Standifird, William Bradley, and Martin David Matthews. "Real Time Basin Modeling: Improving Geopressure and Earth Stress Predictions." Paper presented at the SPE Offshore Europe Oil and Gas Exhibition and Conference, Aberdeen, United Kingdom, September 2005. doi: https://doi.org/10.2118/96464-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu nav search search input Search input auto suggest search filter All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Offshore Europe Conference and Exhibition Search Advanced Search AbstractBasin modeling is an effective tool for pore pressure prediction. A model that can be updated as new data is acquired can provide a Look Ahead prediction that may bevalid for several thousand feet ahead of the bit.A new modeling program is described that has proven effective both in pre-drill analysis and in while-drilling situations for a variety of geologic regimes.In the recently completed DEA 119 Phase 2 study, pressure gradients were predicted to less s than 1 ppg for the whole well in 62% of blind test analyses.In numerous wells, real time updating of the basin model has proved effective at narrowing the envelope of pore pressure and Earth stress uncertainty ahead of the bit.The model utilizes conventional compaction principles derived from seismic and/or well gradient logs as calibration. It combines this information with geologic-based information (ages, thickness, porosity and lithology) to predict the geopressure environment that will be encountered by the well.As the well is drilled, new information becomes available that will either confirm or refute the original geopressure prediction.This new data is well-specific and can be used to update the basin model.The data ahead of the bit still contains all of the information that is known about the area and has not been changed by the addition of the real time data.Adjusting the model withthe newly acquired data will therefore reduce the envelope of uncertainty that existed in the original model and update the prediction with the new information.This updating is performed in real time and is available while the well is being drilled.An early example of basin modeling in a real time look ahead mode is shown to demonstrate the challenges that have been addressed to date.Through careful examination of a case where performance could have been better, the authors reveal the weaknesses of the approach such that they can be better understood. Furthermore, the example demonstrates the capability to update the prediction of pore pressure ahead of the bit and use this advance prediction for other solutions such as wellbore stability computations.Aggregated look ahead performance results from five other projects are revealed that demonstrate the ability of this technology to provide information to operators that can improve the safety and performance of well construction.IntroductionRecent multi-year analysis suggests abnormal pressure and wellbore instability represent 30–50% of non-productive time during well construction[1].Failure to correctly anticipate subsurface environment in well planning can cause over or under-design of the tubular and fluids programs resulting in excess construction costs, sidetracks, and inability to reach geologic objectives. Proper planning can reduce these problems; however, real time model updating (a.k.a. surveillance) can not only minimize downtime, it can save casing strings and enable success where operating based on the original plan will result in failure. Monitoring shale pressures with logging while drilling measurements and petrophysical techniques is a reactive approach that requires the formation to be exposed, sometimes over a hundred feet, before an analysis can be performed.The purpose of this paper is to describe a pro-active approach, using fit for purpose pore pressure and Earth stress forward modeling technology, to improve the success and efficiency of well construction. Keywords: basin modeling, drilling, knowledge system inc, real time system, wellbore integrity, artificial intelligence, expert system, correlation, petrophysical analysis, real-time basin modeling Subjects: Wellbore Design, Reservoir Characterization, Wellbore integrity, Reservoir geomechanics This content is only available via PDF. 2005. Society of Petroleum Engineers You can access this article if you purchase or spend a download.
Abstract Basin modeling is an effective tool for pore pressure prediction. A model that can be updated as new data is acquired can provide a Look Ahead prediction that may be valid for several thousand feet ahead of the bit.A new modeling program is described that has proven effective both in pre-drill analysis and in while-drilling situations for a variety of geologic regimes. In the recently completed DEA 119 Phase 2 study, pressure gradients were predicted to less s than 1 ppg for the whole well in 62% of blind test analyses. In numerous wells, real time updating of the basin model has proved effective at narrowing the envelope of pore pressure and Earth stress uncertainty ahead of the bit. The model utilizes conventional compaction principles derived from seismic and/or well gradient logs as calibration. It combines this information with geologic-based information (ages, thickness, porosity and lithology) to predict the geopressure environment that will be encountered by the well. As the well is drilled, new information becomes available that will either confirm or refute the original geopressure prediction. This new data is well-specific and can be used to update the basin model. The data ahead of the bit still contains all of the information that is known about the area and has not been changed by the addition of the real time data. Adjusting the model with the newly acquired data will therefore reduce the envelope of uncertainty that existed in the original model and update the prediction with the new information. This updating is performed in real time and is available while the well is being drilled. An early example of basin modeling in a real time look ahead mode is shown to demonstrate the challenges that have been addressed to date. Through careful examination of a case where performance could have been better, the authors reveal the weaknesses of the approach such that they can be better understood.Furthermore, the example demonstrates the capability to update the prediction of pore pressure ahead of the bit and use this advance prediction for other solutions such as wellbore stability computations. Aggregated look ahead performance results from five other projects are revealed that demonstrate the ability of this technology to provide information to operators that can improve the safety and performance of well construction.
Modern petroleum and petrotechnical engineering is increasingly challenging due to the inherently scarce and decreasing number of global petroleum resources. Exploiting these resources efficiently will require researchers, scientists, engineers and other practitioners to develop innovative mathematical solutions to serve as basis for new asset deve
The expansion of unconventional petroleum resources in the recent decade and the rapid development of computational technology have provided the opportunity to develop and apply 3D numerical modeling technology to simulate the hydraulic fracturing of shale and tight sand formations. This book presents 3D numerical modeling technologies for hydraulic fracturing developed in recent years, and introduces solutions to various 3D geomechanical problems related to hydraulic fracturing. In the solution processes of the case studies included in the book, fully coupled multi-physics modeling has been adopted, along with innovative computational techniques, such as submodeling. In practice, hydraulic fracturing is an essential project component in shale gas/oil development and tight sand oil, and provides an essential measure in the process of drilling cuttings reinjection (CRI). It is also an essential measure for widened mud weight window (MWW) when drilling through naturally fractured formations; the process of hydraulic plugging is a typical application of hydraulic fracturing. 3D modeling and numerical analysis of hydraulic fracturing is essential for the successful development of tight oil/gas formations: it provides accurate solutions for optimized stage intervals in a multistage fracking job. It also provides optimized well-spacing for the design of zipper-frac wells.Numerical estimation of casing integrity under stimulation injection in the hydraulic fracturing process is one of major concerns in the successful development of unconventional resources. This topic is also investigated numerically in this book. Numerical solutions to several other typical geomechanics problems related to hydraulic fracturing, such as fluid migration caused by fault reactivation and seismic activities, are also presented. This book can be used as a reference textbook to petroleum, geotechnical and geothermal engineers, to senior undergraduate, graduate and postgraduate students, and to geologists, hydrogeologists, geophysicists and applied mathematicians working in this field. This book is also a synthetic compendium of both the fundamentals and some of the most advanced aspects of hydraulic fracturing technology.
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