The Experts below are selected from a list of 360 Experts worldwide ranked by ideXlab platform
Yingchao Huang - One of the best experts on this subject based on the ideXlab platform.
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A correlation of steam chamber size and temperature falloff in the early-period of the SAGD Process
Fuel, 2015Co-Authors: Lijuan Zhu, Zeng Fanhua, Yingchao HuangAbstract:Abstract Steam Assisted Gravity Drainage (SAGD) is a widely-used thermal oil recovery technique in western Alberta’s oil sands reservoirs. Because of reservoir heterogeneity, the Wellbore Hydraulics and undulation, non-uniform steam chambers will evolve. Numerical simulation allows for the practical prediction of steam chamber size in SAGD. However, the long computation time in 3D scenarios and the impact of uncertainties in input parameters limit its application. In this paper, a numerical simulation based correlation between steam chamber size and temperature falloff data during shut-in was developed in the early period of the SAGD process which is before the moment that the steam chamber starts spreading laterally. The temperature falloff responses and the corresponding steam chamber sizes at different locations in the producer along the lateral were obtained though 3D numerical simulation studies. Based on the simulation results, a correlation among steam chamber, the temperature falloff rate and the height of liquid level in the producer was derived through regression analysis. The same correlation equation with different coefficients was also found at different shut-in times. The applicability of the proposed correlation in estimating steam chamber sizes along horizontal well is also investigated and validated. A synthetic case study shows that the chamber sizes obtained from the correlation and from simulation are in good agreement and also suggests that this correlation is applicable to estimate the chamber size distribution along the horizontal well at the early period of SAGD process.
Eric Van Oort - One of the best experts on this subject based on the ideXlab platform.
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Utilizing look-up tables representing all models in an automation control architecture to independently handle uncertainties in sensed data in oil and gas well construction
United States Patent and Trademark Office, 2016Co-Authors: Pradeepkumar Ashok, Adrian Ambrus, Parham Pournazari, Roman Shor, Eric Van OortAbstract:A method, system and computer program product for utilizing look-up tables representing all models in an automation control architecture to independently handle uncertainties in sensed data. Data is stored in a form of conditional probability tables (CPTs) or conditional probability distributions (CPDs), where the data comes from an operator, a service provider, a drilling contractor and an equipment manufacturer. Models of the drilling process domains, such as Wellbore Hydraulics, drill bit/rock interactions, torque and drag modeling, vibration modeling and drilling machinery operation, are received. Data is extracted from these models into the CPTs or CPDs. The CPTs or CPDs are converted to look-up tables. Data in the look-up tables are then visually displayed in graphical form. As a result, real-time troubleshooting of drilling operations occurs in an efficient manner.Board of Regents, University of Texas Syste
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Determination of drilling fluid rheology under downhole conditions by using real-time distributed pressure data
Journal of Natural Gas Science and Engineering, 2015Co-Authors: A. Karimi Vajargah, Eric Van OortAbstract:One the most important tasks during any drilling operation is to measure rheological properties of drilling fluids to allow for optimum maintenance and Wellbore Hydraulics management. In current drilling practice, such measurement is routinely carried out by a mud engineer at the rig site using test protocols and equipment that quantify the relationship between the fluid's shear stress and shear rate, as standardized by the American Petroleum Institute (API). Usually, measurements are conducted at atmospheric pressure and standardized temperature and are therefore generally not representative of actual downhole pressure and temperature conditions. High Pressure High Temperature (HPHT) viscometers can of course be used at the drilling fluid design stage to determine its rheological properties under downhole condition. However, these properties are subjected to change during drilling operations due to variation in mud maintenance and the introduction of drilling solids and contaminations. In addition, installation of a HPHT viscometer at the rig site is highly impractical due to its cost, maintenance, calibration difficulties, and lack of dedicated personnel to run the equipment.This paper presents a novel method to determine mud rheological parameters in real-time by using downhole sensor data. The well itself is used as the equivalent of a large pipe viscometer, with pressure measurements conducted along its length using multiple sensors placed at strategic positions in the drillstring. Contrary to traditional methods, rheology determination is performed at actual downhole pressure and temperature, without any human interaction and without the need for any rheology measurement equipment on surface. Frictional pressure loss is recorded at several flow rates, preferably while ramping up pump rates after making connections, and parameters associated with two- and three-parameter rheological models (e.g. the n, K and τy parameters of the Yield Power Law (YPL) also known as Herschel-Bulkley model, which most accurately describes the majority of drilling fluids) are derived. In addition, time-dependent fluid characteristics such as gel strength can also be quantified using this method. Pressure data sets from wired drillpipe during field trials with a 12.6ppg and 13.1ppg synthetic based muds were used to validate the applicability of the new method in the field. These validations show that the method can be applied successfully in the field when downhole distributed pressure data is available.This novel approach represents a significant step in the direction of achieving full automation of drilling fluid property monitoring and maintenance with an elegant method that requires no human interaction, eliminating the need for surface measurement equipment, while at the same time representing more accurately the downhole pressure and temperature environment. Given the importance of accurate rheology characterization, particularly in the new era of active annular pressure management using Managed Pressure Drilling (MPD) and Dual Gradient Drilling (DGD) techniques that rely heavily on accurate Hydraulics modeling, the benefits are self-evident.
Lijuan Zhu - One of the best experts on this subject based on the ideXlab platform.
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A correlation of steam chamber size and temperature falloff in the early-period of the SAGD Process
Fuel, 2015Co-Authors: Lijuan Zhu, Zeng Fanhua, Yingchao HuangAbstract:Abstract Steam Assisted Gravity Drainage (SAGD) is a widely-used thermal oil recovery technique in western Alberta’s oil sands reservoirs. Because of reservoir heterogeneity, the Wellbore Hydraulics and undulation, non-uniform steam chambers will evolve. Numerical simulation allows for the practical prediction of steam chamber size in SAGD. However, the long computation time in 3D scenarios and the impact of uncertainties in input parameters limit its application. In this paper, a numerical simulation based correlation between steam chamber size and temperature falloff data during shut-in was developed in the early period of the SAGD process which is before the moment that the steam chamber starts spreading laterally. The temperature falloff responses and the corresponding steam chamber sizes at different locations in the producer along the lateral were obtained though 3D numerical simulation studies. Based on the simulation results, a correlation among steam chamber, the temperature falloff rate and the height of liquid level in the producer was derived through regression analysis. The same correlation equation with different coefficients was also found at different shut-in times. The applicability of the proposed correlation in estimating steam chamber sizes along horizontal well is also investigated and validated. A synthetic case study shows that the chamber sizes obtained from the correlation and from simulation are in good agreement and also suggests that this correlation is applicable to estimate the chamber size distribution along the horizontal well at the early period of SAGD process.
Shifeng Tian - One of the best experts on this subject based on the ideXlab platform.
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advanced geothermal Wellbore Hydraulics model
Journal of Energy Resources Technology-transactions of The Asme, 2000Co-Authors: Shifeng Tian, John T FingerAbstract:A model has been developed to simulate multiphase flow in the Wellbore and heat transfer processes between the well and formations. The model is capable of handling dynamic well depth during drilling, varying flow regimes in multiphase flow, phase change between liquid and gas, and kicks or lost circulation depending on the pressure difference between the Wellbore annulus and formation. The model requires simple data input and is able to handle complicated drilling cases such as casing installation, changing drilling fluids, and drillpipe/coiled tubing connections during drilling operations.
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Multiphase hydrodynamic analysis of pneumatic transportation ofdrill cuttings in air drilling
Powder Technology, 1993Co-Authors: Michael A. Adewumi, Shifeng TianAbstract:Abstract Analysis of Wellbore Hydraulics is motivated by the need for improved understanding of this system so as to enhance air drilling operation. A viable Wellbore Hydraulics model is utilized as the basis for this study. Several important parameters that influence air drilling operations are analyzed, such as drill cutting size and size distribution, hole size changes, attrition, and particle shape. This work defines several areas that need special investigation and sheds light on several previously unanswered questions. The most salient findings are that hole size changes, cuttings size and size distribution and particle shape affect the Wellbore Hydraulics very significantly. The analysis leads to the evolution of a clear explanation for choking in air drilling.
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Development of hydrodynamic-model-based air-drilling design procedures
1992Co-Authors: Shifeng Tian, M. A. AdewumiAbstract:The lack of systematic analysis of the Hydraulics involved in air drilling has inhibited the development and utilization of air-drilling technology because the optimal design of any drilling program requires thorough knowledge of the Wellbore Hydraulics. A comprehensive study of air-drilling Hydraulics yielded the system model used as the basis for a viable systematic set of design procedures. The system model was developed by coupling the models for air flow in the drillstring, air flow through the bit nozzles, and pneumatic transport of cuttings in the annulus. The resulting system model was used to design an air-drilling program
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Determination of optimal air flow rate in air drilling
Journal of Petroleum Science and Engineering, 1992Co-Authors: Michael A. Adewumi, Shifeng TianAbstract:Abstract Optimal design of any drilling program requires good knowledge of Wellbore Hydraulics. Established techniques are available for formulating some understanding of the associated Wellbore Hydraulics for conventional mud drilling, but this is not the case for air drilling. The Wellbore Hydraulics of air drilling present distinctly different problems from those associated with mud drilling. A systematic study of these problems, especially utilizing fundamental approaches, is lacking. This study addresses this problem using a fundamental, hydrodynamic multiphase flow model for air drilling. Extensive parametric analysis of the system is performed to validate the viability of the model as a predictive tool. The model is demonstrably capable of predicting the pressure-drop profile in the annulus and the optimal lifting velocity, an essential ingredient in the optimal design of air drilling. The results demonstrate the ability of the model to predict a number of phenomena that are associated with lifting cuttings from the hole during air drilling. The model possesses scale-up capability.
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multiphase hydrodynamic model predicts important phenomena in air drilling Hydraulics
Spe Drilling Engineering, 1991Co-Authors: Shifeng TianAbstract:Development of a model to determine optimal lifting velocity. The model accommodates non-uniformity in particle sizes and predicts the pressure-drop profile in the annulus under various simulated drilling conditions. It is capable of serving design, predictive, and descriptive purposes for air-drilling Wellbore Hydraulics, even for two particle sizes.
Karsten Pruess - One of the best experts on this subject based on the ideXlab platform.
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ON THE FEASIBILITY OF USING SUPERCRITICAL CO2 AS HEAT TRANSMISSION FLUID
2014Co-Authors: Engineered Hot, Dry Rock, Geothermal System, Karsten Pruess, Mohamed AzaroualAbstract:Responding to the need to reduce atmospheric emissions of carbon dioxide, Donald Brown (2000) proposed a novel hot dry rock (HDR) concept that would use CO2 as heat transmission fluid, and would achieve geologic sequestration of CO2 as an ancillary benefit. Following up on his suggestion, we have evaluated thermophysical properties and performed numerical simulations to explore the fluid dynamics and heat transfer issues in a HDR reservoir that would be operated with CO2. We find that CO2 is roughly comparable to water in its ability to mine heat from hot fractured rock. CO2 has certain advantages with respect to Wellbore Hydraulics, where larger compressibility and expansivity and lower viscosity as compared to water would reduce the parasitic power consumption of the fluid circulation system. Chemical interactions induced by CO2 between fluids and rocks suggest a potential for porosity enhancement and reservoir growth. A HDR system running on CO2 has sufficiently attractive features to warrant further investigation
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numerical studies of fluid rock interactions in enhanced geothermal systems egs with co2 as working fluid
Lawrence Berkeley National Laboratory, 2008Co-Authors: Tianfu Xu, Karsten Pruess, John A AppsAbstract:PROCEEDINGS, Thirty-Third Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, January 28-30, 2008 SGP-TR-185 NUMERICAL STUDIES OF FLUID-ROCK INTERACTIONS IN ENHANCED GEOTHERMAL SYSTEMS (EGS) WITH CO 2 AS WORKING FLUID Tianfu Xu, Karsten Pruess and John Apps Earth Sciences Division Lawrence Berkeley National Laboratory One Cyclotron Road Berkeley, California, 94506, USA E-mail: Tianfu_Xu@lbl.gov ABSTRACT There is growing interest in the novel concept of operating Enhanced Geothermal Systems (EGS) with CO 2 instead of water as heat transmission fluid. Initial studies have suggested that CO 2 will achieve larger rates of heat extraction, and can offer geologic storage of carbon as an ancillary benefit. Fluid-rock interactions in EGS operated with CO 2 are expected to be vastly different in zones with an aqueous phase present, as compared to the central reservoir zone with anhydrous supercritical CO 2 . Our numerical simulations of chemically reactive transport show a combination of mineral dissolution and precipitation effects in the peripheral zone of the systems. These could impact reservoir growth and longevity, with important ramifications for sustaining energy recovery, for estimating CO 2 loss rates, and for figuring tradeoffs between power generation and geologic storage of CO 2 . INTRODUCTION The U.S. Department of Energy has broadly defined Enhanced (or Engineered) Geothermal Systems (EGS) as engineered reservoirs that have been created to extract economical amounts of heat from geothermal resources of low permeability and/or porosity (MIT, 2006). The MIT report indicated that EGS could become a major supplier of primary energy for U.S. base-load generation capacity by 2050. Here we consider a novel EGS concept that would use carbon dioxide (CO 2 ) instead of water as heat transmission fluid, and would achieve geologic sequestration of CO 2 as an ancillary benefit (Brown, Numerical simulations of fluid dynamics and heat transfer indicate that CO 2 is superior to water in its ability to mine heat from hot fractured rock (Pruess, 2006). Carbon dioxide also offers advantages with respect to Wellbore Hydraulics, in that its larger compressibility and expansivity as compared to water would increase buoyancy forces and reduce the parasitic power consumption of the fluid circulation system. While the thermal and hydraulic aspects of a CO 2 -EGS system look promising, major uncertainties remain with regard to chemical interactions between fluids and rocks. Figure. 1. Schematic showing portions of the three zones with different phase compositions in an EGS operated with CO 2 . The model domain studied in this paper is in the single-phase Zone 3, extending from the two-phase Zone 2 on the left to the outer boundary of the EGS on the right.”sc” stands for supercritical CO 2 . As shown in Figure 1, a fully developed EGS with CO 2 would consist of three distinct zones (Fouillac et al., 2004; Ueda et al., 2005), (1) a central zone or
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enhanced geothermal systems egs using co2 as working fluid a novel approach for generating renewable energy with simultaneous sequestration of carbon
Geothermics, 2006Co-Authors: Karsten PruessAbstract:Responding to the need to reduce atmospheric emissions of carbon dioxide, Donald Brown (2000) proposed a novel enhanced geothermal systems (EGS) concept that would use CO{sub 2} instead of water as heat transmission fluid, and would achieve geologic sequestration of CO{sub 2} as an ancillary benefit. Following up on his suggestion, we have evaluated thermophysical properties and performed numerical simulations to explore the fluid dynamics and heat transfer issues in an engineered geothermal reservoir that would be operated with CO{sub 2}. We find that CO{sub 2} is superior to water in its ability to mine heat from hot fractured rock. CO{sub 2} also has certain advantages with respect to Wellbore Hydraulics, where larger compressibility and expansivity as compared to water would increase buoyancy forces and would reduce the parasitic power consumption of the fluid circulation system. While the thermal and hydraulic aspects of a CO{sub 2}-EGS system look promising, major uncertainties remain with regard to chemical interactions between fluids and rocks. An EGS system running on CO{sub 2} has sufficiently attractive features to warrant further investigation.
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enhanced geothermal systems egs using co2 as working fluid a novel approach for generating renewable energy with simultaneous sequestration of carbon
Geothermics, 2006Co-Authors: Karsten PruessAbstract:Responding to the need to reduce atmospheric emissions of carbon dioxide, Brown [Brown, D., 2000. A Hot Dry Rock geothermal energy concept utilizing supercritical CO2 instead of water. In: Proceedings of the Twenty-Fifth Workshop on Geothermal Reservoir Engineering, Stanford University, pp. 233–238] proposed a novel enhanced geothermal systems (EGS) concept that would use carbon dioxide (CO2) instead of water as heat transmission fluid, and would achieve geologic sequestration of CO2 as an ancillary benefit. Following up on his suggestion, we have evaluated thermophysical properties and performed numerical simulations to explore the fluid dynamics and heat transfer issues in an engineered geothermal reservoir that would be operated with CO2. We find that CO2 is superior to water in its ability to mine heat from hot fractured rock. Carbon dioxide also offers certain advantages with respect to Wellbore Hydraulics, in that its larger compressibility and expansivity as compared to water would increase buoyancy forces and would reduce the parasitic power consumption of the fluid circulation system. While the thermal and hydraulic aspects of a CO2-EGS system look promising, major uncertainties remain with regard to chemical interactions between fluids and rocks. An EGS system running on CO2 has sufficiently attractive features to warrant further investigation.
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Enhanced geothermal systems (EGS) using CO2 as working fluid - A novelapproach for generating renewable energy with simultaneous sequestration of carbon
Lawrence Berkeley National Laboratory, 2006Co-Authors: Karsten PruessAbstract:Submitted to Geothermics, June 2006 LBNL-60397 Enhanced Geothermal Systems (EGS) Using CO 2 as Working Fluid – A Novel Approach for Generating Renewable Energy with Simultaneous Sequestration of Carbon Karsten Pruess Earth Sciences Division, Lawrence Berkeley National Laboratory Berkeley, CA 94720 K_Pruess@lbl.gov Abstract Responding to the need to reduce atmospheric emissions of carbon dioxide, Donald Brown (2000) proposed a novel enhanced geothermal systems (EGS) concept that would use CO 2 instead of water as heat transmission fluid, and would achieve geologic sequestration of CO 2 as an ancillary benefit. Following up on his suggestion, we have evaluated thermophysical properties and performed numerical simulations to explore the fluid dynamics and heat transfer issues in an engineered geothermal reservoir that would be operated with CO 2 . We find that CO 2 is superior to water in its ability to mine heat from hot fractured rock. CO 2 also has certain advantages with respect to Wellbore Hydraulics, where larger compressibility and expansivity as compared to water would increase buoyancy forces and would reduce the parasitic power consumption of the fluid circulation system. While the thermal and hydraulic aspects of a CO 2 - EGS system look promising, major uncertainties remain with regard to chemical interactions between fluids and rocks. An EGS system running on CO 2 has sufficiently attractive features to warrant further investigation.