The Experts below are selected from a list of 312 Experts worldwide ranked by ideXlab platform
Dennis Denney - One of the best experts on this subject based on the ideXlab platform.
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Integrated Completion Design for Horizontal Wells in Unconventional Reservoirs
Journal of Petroleum Technology, 2012Co-Authors: Dennis DenneyAbstract:This article, written by Senior Technology Editor Dennis Denney, contains highlights of paper SPE 147120, ’An Integrated Approach To Design Completions for Horizontal Wells in Unconventional Reservoirs,’ by R. Jain, SPE, S. Syal, SPE, T. Long, SPE, and C. Wattenbarger, SPE, ExxonMobil, and I. Kosik, SPE, Imperial Oil Resources, prepared for the 2011 SPE Annual Technical Conference and Exhibition, Denver, 30 October-2 November. The paper has not been peer reviewed. An integrated workflow was tested for Designing Completions for a heavy-oil-recovery process that involves injection and production through the same wellbore. To capture the effect of variations or uncertainties in reservoir and fluid-flow characteristics over time, the transient effects are particularly important while analyzing the long-term performance for these types of Completions. The proposed integrated workflow involves initial screening and selection of flow-restricting Completions that can meet the desired injection and production performance on the basis of a detailed wellbore-hydraulics-modeling tool. Introduction Producing heavy oil and bitumen involves technologies such as cold mining for shallower resources or in-situ viscosity reduction. The cyclic solvent-based process involves alternating cycles of injecting a viscosity-reducing solvent into the reservoir followed by production of a mixture of heavy oil and solvent, with reduced viscosity, through the same wellbore. Many cyclic-process implementations are intended for use in horizontal wells. The Completion Design for such a process involves ensuring good solvent distribution into the reservoir during the injection phase to mobilize the resource along the entire wellbore and maximize the well length to reduce field-development cost. The process of injecting and producing from the same wellbore entails additional constraints on the Completion Design. One constraint is controlled injection distribution by use of flow-restriction devices such as orifices while maintaining a minimal pressure drop across the Completion during the production phase. Another challenge results from the adverse mobility ratio of the solvent mixture and bitumen during the injection process, which could result in viscous fingering. This fingering can cause wide variations in the solvent injection and may cause an undesirable pressure distribution within the reservoir, which, in turn, may affect solvent placement. Predicting such differential injection or a thief zone is difficult because of the inherent nature of instabilities associated with the fingering process.
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Completion Design for Downhole Water and Oil Separation and Invert Coning
Journal of Petroleum Technology, 1998Co-Authors: Dennis DenneyAbstract:This article is a synopsis of paper SPE 38829, "Completion Design for Downhole Water and Oil Separation and Invert Coning," by Arthur Loginov, Baker Oil Tools, and Christopher Shaw, Centrilift, originally presented at the 1997 SPE Annual Technical Conference and Exhibition, San Antonio, Texas, 5-8 October.
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Meeting Deepwater Subsea-Completion Design Challenges
Journal of Petroleum Technology, 1997Co-Authors: Dennis DenneyAbstract:This article is a synopsis of paper SPE 36991, "Meeting the Challenges of Deepwater Subsea-Completion Design," by Don Aldridge, SPE, Baker Oil Tools, and Paul Dodd, Independent Consultant originally presented at the 1996 SPE Asia Pacific Oil and Gas Conference, Adelaide, Australia, 28-31 October.
Don Aldridge - One of the best experts on this subject based on the ideXlab platform.
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Meeting the Challenges of Deepwater Subsea Completion Design
All Days, 1996Co-Authors: Don Aldridge, Paul DoddAbstract:Abstract Significant technological advances in methods and equipment have permitted increased drilling in deeper waters, often beyond continental shelves. Completion techniques have also advanced to allow efficient deepwater production. When Designing a deepwater or subsea Completion, traditional downhole challenges are complicated by subsea wellhead conditions that require advanced practices and equipment. This paper will acquaint the reader with characteristics unique to deepwater, subsea Completions and present new Completion accessories that maximize performance throughout the life of the well. Included will be a case study of a new use of electronics, dynamic seal assemblies and deepwater subsurface safety systems by an operator in deepwater Gulf of Mexico. Introduction When considering deepwater exploitation, not only are the issues of wellhead changed, but also downhole equipment must be modified due to surface and ocean floor conditions. In the Design and installation phase of the Completion and subsequent life of the well, the presence of certain Design parameters and the ease of installation must be considered as well as how any future stimulation, intervention or workover will be accomplished and/or accommodated. This paper will put forth thought processes that must go into a subsea Completion Design and present a deepwater Completion typical of those being used in the Gulf of Mexico. Tubular Design Tubular Design must address some unique aspects of a subsea Completion. In addition to wellhead placement on the ocean floor, many wells are highly deviated to horizontal, with obvious impact on tubular and production string Design. Stimulation. The tubular Design must address any future well intervention or stimulation modes. The stimulation mode differs in a subsea Completion from that of a surface Completion. Temperature versus depth, from the surface, increases in a linear fashion in most surface or shallow water Completions (Fig 1). The subsea Completion temperature increase is not linear. As fluids are pumped from the surface, they are cooled by surrounding waters until the wellhead depth is reached, at which time the temperature versus depth begins to increase in a linear fashion (Fig 2). P. 279
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Multi Zone Completion Design Considerations
All Days, 1996Co-Authors: Don AldridgeAbstract:Very often, a wellbore penetrates numerous geologic zones of interest. An optimum Completion Design addresses a method of isolating these zones while protecting the reservoir for future exploitation. A common practice is to utilize two or more packers for efficient zonal isolation. When Designing such a Completion, a number of conditions and phenomena must be considered. These include, among others : thermal expansion ; pressure changes ; piston effects, and their resultant force and/or length changes. This paper outlines some of the factors that must be taken into consideration, then presents specific challenges and viable solutions for typical multi-tandem Completion Designs.
G. M. Watson - One of the best experts on this subject based on the ideXlab platform.
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Challenges in deepwater subsea well Completion Design and implementation
2003Co-Authors: J. Piedras, G. P. Stimatz, V. B. Nielsen, G. M. WatsonAbstract:The subsea well Completion Design and implementation in Total's Aconcagua field and Marathon Oil Co.'s Camden Hills field posed unprecedented challenges.
Giin-fa Fuh - One of the best experts on this subject based on the ideXlab platform.
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Completion Design Using Sand Management Approach Based on Sanding Prediction Analysis for HPHT Gas Wells
All Days, 2014Co-Authors: Giin-fa Fuh, Manabu NozakiAbstract:Abstract This paper outlines our selection of well Completion Design based on the results of sand production prediction for each of the development wells and the total sand production to be expected from the field. The methodology on the formation failure and modeling analysis for sand production and sand rate prediction is provided for the HPHT gas and gas condensate field located offshore in the UK's Central North Sea. Sand production caused by the failure of reservoir formations through pressure depletion and drawdown pressure could lead to a significant loss in well production, well/facility damage or ultimately total well failure. The key objective of this evaluation and sand rate prediction analysis was to develop a well Completion Design that will deliver effective sand control throughout the producing life of the field. Over the field life it is both critical and prudent to predict the sanding potential of a given reservoir during continuous well production for any Completion Design under consideration. This paper illustrates our comprehensive geomechanics investigation for sanding potential and sand rate prediction analysis for all the planned wells to be drilled and completed in the very thick sandstone reservoirs. We'll also show that if the reservoir rock strength and its variability along depth are properly measured for each well (through well core testing and log data analysis), the conditions that induce sand production issues for each specific interval could be predicted. In addition, the most important factors contributing to sanding problems have been identified to be the rock strength, flowing bottom-hole pressure, reservoir pressure, in-situ stresses, and flow rate. Therefore if permeability distribution and oil/gas and water saturations were measured (for each well) in addition to the reservoir rock strength, the optimal Completion method to reduce the likelihood of sand production problems without significantly impacting production could be found. A 3D non-linear elastic-plastic finite element model incorporated with a fluid-flow module (reservoir component) has been effectively used to conduct such analysis. The key findings from this investigation can be summarized as follows: The sand production rates based on the planned reservoir depletion and production schedules are predicted for each of the eight wells as planned for the field development; We can further update the original sand rate prediction model using the new rock strength and permeability/porosity test results obtained from the immediate testing of the new well cores as retrieved from one of the early development wells; The predicted sand rates in both daily and total sand production are low enough to warrant our sand management (rather than sand exclusion) approach to this new field; and The sand prediction results enable us to come up with optimal well platform/facility Design to cope with the predicted sand rates to be produced throughout the reservoir life. The production engineers can also make sure that the overall safety of the facility is to be achieved by conducting regular and periodic inspections of any likely sand erosion for the surface chokes or pipes in the wells that especially have been forecast to produce more prolifically with relatively higher sand rates.
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Sand Production Prediction Analysis of Heterogeneous Reservoirs for Sand Control and Optimal Well Completion Design
All Days, 2013Co-Authors: Giin-fa Fuh, Nobuo MoritaAbstract:Abstract This paper provides our approach to making sand production and sand rate prediction analysis for a gas and gas condensate field located offshore in the South Natuna Sea. Since the reservoirs are very heterogeneous and containing four major layers or producing intervals, the prediction of their sanding potential becomes more complex and thus requires a more elaborate and sound judgment to make a reasonable assessment. The key objective of this evaluation and sand rate prediction is to come up with an optimal plan for well Completion Design and providing effective sand control throughout the life of such multiple reservoirs. Sand production due to the failure of reservoir formation resulting from pressure depletion and drawdown pressure often causes significant loss in well production, facility damage, and can ultimately lead to shut-in of the well after continuous sanding-up. It is most worthwhile if we are able to predict the sanding potential of any given reservoir during continuous well production under certain Completion Design. Our ability to reliably predict such sanding potential and sand production rate can help generate an optimum Design for well Completion by running a series of computer simulations for various Design scenarios. Our study showed that if the reservoir rock strength and its variation along the depth were measured for each well, the conditions that induce sand production problem for each interval could be predicted. The most important factors contributing to sanding problems were the rock strength, flowing bottom-hole pressure, reservoir pressure, in-situ stresses, and flow rate. Therefore, if permeability distribution and oil/gas and water saturations were measured for each well in addition to the rock strength, the best Completion method to reduce sand problems without significantly decreasing oil or gas production can be identified without going through the costly trial-and-error selection method in the actual field. A 3D non-linear elastic-plastic finite element model incorporated with fluid-flow module for reservoir component has been effectively used for such numerical simulations. The results of this investigation conclude the following key points for optimal and effective well Completion Design:there are sporadic weak sands found in all four major intervals of the reservoirs and it's not possible to use a selective perforation scheme for this field;the average sand rate as predicted is too high so that at least half of the high sand producers will require an installation of some downhole sand control measures;The installation of a sand rate detection device at around the flow-line elbows is necessary and prudent;It is necessary to monitor the amount of sand production using equipments such as sand traps, sand rate measurement devices, and erosion coupons for better protection or timely replacement of the critical lines and flow pipes;produce the reservoir with smooth reduction of reservoir pressure by limiting the drawdown pressure to be 250 psi or smaller in order to reduce the sand rate by 50–75%.
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Use of Reservoir Formation Failure and Sanding Prediction Analysis for Viable Well-Construction and Completion-Design Options
All Days, 2006Co-Authors: Giin-fa Fuh, Ian Ramshaw, Kerry C. Freedman, Nabeel A. Abdelmalek, Nobuo MoritaAbstract:Abstract Using two field case examples, this paper presents our current well construction and Completion Design analysis based on the following approach:carry out detailed evaluation or determination of reservoir formation strength distribution using core testing, log data and drilling data analysis for rock strength estimate and its correlation with core testing results;conduct a series of triaxial tests on selected reservoir core samples in the low to intermediate strength range for defining the stress-strain relationship (or material laws), rock failure and yield criteria, and other non-linear rock parameters required for numerical modeling analysis;perform a series of formation failure and sanding potential analysis for a variety of possible well Completion Design scenarios using 3-D finite element technique for rock structure coupled with well production and fluid flow simulation. The types of Completion Design analyzed include cased hole Completion using conventional perforations or stress-oriented perforations in inclined or high-angle well, openhole Completion in high-angle or horizontal well, screen failure analysis in openhole Completion, etc. In addition to investigating the mechanical response of the rock formations in each Completion Design, the model simulates both well drawdown and reservoir depletion effects on sand failure potential throughout the reservoir life. The results of such systematic study provide useful guidelines on well Design and Completion strategy for sand control or sand management in order to optimize well productivity. The two case examples presented in this paper highlight the use of this technique and approach. We have used this type of analysis and process for the well Design in our business operations around the world with good success. Based on our case example analyses and the specific rock failure characteristics as defined in the laboratory testing results and subsequent numerical simulations of sanding behavior, we are able to identify the most viable well construction and Completion Design for achieving a superior well deliverability and productivity for the long term, minimizing problems due to unintended solid influx and/or loss of well integrity over the reservoir life. The two field case examples in the North Sea as presented demonstrate and highlight the fundamental concept, methodology and the procedures for conducting the well Design analysis through a series of computer simulations of various options for well Completion schemes. The field example results will also show the effective use of rock failure characteristics by the engineers for the control of critical flowing bottom-hole pressure in relation to the reservoir drawdown and depletion to avoid premature sand failures during well production.
Nobuo Morita - One of the best experts on this subject based on the ideXlab platform.
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Sand Production Prediction Analysis of Heterogeneous Reservoirs for Sand Control and Optimal Well Completion Design
All Days, 2013Co-Authors: Giin-fa Fuh, Nobuo MoritaAbstract:Abstract This paper provides our approach to making sand production and sand rate prediction analysis for a gas and gas condensate field located offshore in the South Natuna Sea. Since the reservoirs are very heterogeneous and containing four major layers or producing intervals, the prediction of their sanding potential becomes more complex and thus requires a more elaborate and sound judgment to make a reasonable assessment. The key objective of this evaluation and sand rate prediction is to come up with an optimal plan for well Completion Design and providing effective sand control throughout the life of such multiple reservoirs. Sand production due to the failure of reservoir formation resulting from pressure depletion and drawdown pressure often causes significant loss in well production, facility damage, and can ultimately lead to shut-in of the well after continuous sanding-up. It is most worthwhile if we are able to predict the sanding potential of any given reservoir during continuous well production under certain Completion Design. Our ability to reliably predict such sanding potential and sand production rate can help generate an optimum Design for well Completion by running a series of computer simulations for various Design scenarios. Our study showed that if the reservoir rock strength and its variation along the depth were measured for each well, the conditions that induce sand production problem for each interval could be predicted. The most important factors contributing to sanding problems were the rock strength, flowing bottom-hole pressure, reservoir pressure, in-situ stresses, and flow rate. Therefore, if permeability distribution and oil/gas and water saturations were measured for each well in addition to the rock strength, the best Completion method to reduce sand problems without significantly decreasing oil or gas production can be identified without going through the costly trial-and-error selection method in the actual field. A 3D non-linear elastic-plastic finite element model incorporated with fluid-flow module for reservoir component has been effectively used for such numerical simulations. The results of this investigation conclude the following key points for optimal and effective well Completion Design:there are sporadic weak sands found in all four major intervals of the reservoirs and it's not possible to use a selective perforation scheme for this field;the average sand rate as predicted is too high so that at least half of the high sand producers will require an installation of some downhole sand control measures;The installation of a sand rate detection device at around the flow-line elbows is necessary and prudent;It is necessary to monitor the amount of sand production using equipments such as sand traps, sand rate measurement devices, and erosion coupons for better protection or timely replacement of the critical lines and flow pipes;produce the reservoir with smooth reduction of reservoir pressure by limiting the drawdown pressure to be 250 psi or smaller in order to reduce the sand rate by 50–75%.
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Use of Reservoir Formation Failure and Sanding Prediction Analysis for Viable Well-Construction and Completion-Design Options
All Days, 2006Co-Authors: Giin-fa Fuh, Ian Ramshaw, Kerry C. Freedman, Nabeel A. Abdelmalek, Nobuo MoritaAbstract:Abstract Using two field case examples, this paper presents our current well construction and Completion Design analysis based on the following approach:carry out detailed evaluation or determination of reservoir formation strength distribution using core testing, log data and drilling data analysis for rock strength estimate and its correlation with core testing results;conduct a series of triaxial tests on selected reservoir core samples in the low to intermediate strength range for defining the stress-strain relationship (or material laws), rock failure and yield criteria, and other non-linear rock parameters required for numerical modeling analysis;perform a series of formation failure and sanding potential analysis for a variety of possible well Completion Design scenarios using 3-D finite element technique for rock structure coupled with well production and fluid flow simulation. The types of Completion Design analyzed include cased hole Completion using conventional perforations or stress-oriented perforations in inclined or high-angle well, openhole Completion in high-angle or horizontal well, screen failure analysis in openhole Completion, etc. In addition to investigating the mechanical response of the rock formations in each Completion Design, the model simulates both well drawdown and reservoir depletion effects on sand failure potential throughout the reservoir life. The results of such systematic study provide useful guidelines on well Design and Completion strategy for sand control or sand management in order to optimize well productivity. The two case examples presented in this paper highlight the use of this technique and approach. We have used this type of analysis and process for the well Design in our business operations around the world with good success. Based on our case example analyses and the specific rock failure characteristics as defined in the laboratory testing results and subsequent numerical simulations of sanding behavior, we are able to identify the most viable well construction and Completion Design for achieving a superior well deliverability and productivity for the long term, minimizing problems due to unintended solid influx and/or loss of well integrity over the reservoir life. The two field case examples in the North Sea as presented demonstrate and highlight the fundamental concept, methodology and the procedures for conducting the well Design analysis through a series of computer simulations of various options for well Completion schemes. The field example results will also show the effective use of rock failure characteristics by the engineers for the control of critical flowing bottom-hole pressure in relation to the reservoir drawdown and depletion to avoid premature sand failures during well production.