The Experts below are selected from a list of 6897 Experts worldwide ranked by ideXlab platform
E. Soldo - One of the best experts on this subject based on the ideXlab platform.
-
Geothermal Repurposing of Depleted Oil and Gas Wells in Italy
Proceedings, 2020Co-Authors: E. Soldo, Claudio Alimonti, Davide ScroccaAbstract:The decarbonisation of the energy sector is probably one of the main worldwide challenges of the future. Global changes urge a radical transformation and improvement of the energy-producing systems to meet the decarbonisation targets and a reduction of greenhouse gas emissions. The hydrocarbon industry also contributes to this transition path. In a mature stage of Oil and gas fields, the production of hydrocarbons is associated with formation waters. The volume of produced water increases with the maturity of the assets and the geothermal repurposing of Depleted Oil and gas wells could be an alternative to the mining closure. In the described transition scenario, the geothermal energy seems very promising because of its wide range of applications depending on the temperature of extracted fluids. This flexibility enables us to propose projects inspired by a circular economic vision considering the integration in the territory and social acceptance issues. In Italy, since 1985, 7246 wells have been drilled for hydrocarbon, of which 898 are located onshore with a productive or potentially productive operational status. This paper presents a preliminary investigation of Oil and gas fields located onshore in Italian territory based on the available information on temperature distribution at different depths. Then, taking into account the local energy demand, existing infrastructure, and land use of the territory, a conversion strategy for the producing wells is proposed for three case studies.
-
Coupling of energy conversion systems and wellbore heat exchanger in a Depleted Oil well
Geothermal Energy, 2016Co-Authors: Claudio Alimonti, D. Bocchetti, Daniela Berardi, E. SoldoAbstract:The conventional geothermal power plants use the reinjection wells mostly to avoid the depletion of the geothermal reservoir gathering in the underground of the produced brine. Nevertheless, reinjection operations entail high economic costs and some risks. An alternative is the extraction of the heat without geothermal fluids production, the wellbore heat exchanger. The goal of the present paper is the analysis of the power production of the wellbore heat exchanger (WBHX) in time and the comparison between two different conversion systems of the thermal energy into electrical: the organic ranking cycle (ORC) plant and the Stirling motor. The selected case study is the Oil field of Villafortuna Trecate, a medium enthalpy geothermal resource. The simulation results show a substantial decrease of the wellhead temperature in the first 6 months. After 1 year, the thermal power extracted with the WBHX is greater than 1.3 MW. The design parameters are 20 m3/h for the flow rate, outlet temperature 100.38 °C and the inlet temperature is 40 °C. The R-C318 has been selected as working fluid in the ORC plant: the net electrical power is 121 kW. The air is the working fluid in the Stirling motor: the evaluated net electrical power is 152 kW. The Stirling engine has an efficiency greater than 41 % compared to a system ORC.
Claudio Alimonti - One of the best experts on this subject based on the ideXlab platform.
-
Geothermal Repurposing of Depleted Oil and Gas Wells in Italy
Proceedings, 2020Co-Authors: E. Soldo, Claudio Alimonti, Davide ScroccaAbstract:The decarbonisation of the energy sector is probably one of the main worldwide challenges of the future. Global changes urge a radical transformation and improvement of the energy-producing systems to meet the decarbonisation targets and a reduction of greenhouse gas emissions. The hydrocarbon industry also contributes to this transition path. In a mature stage of Oil and gas fields, the production of hydrocarbons is associated with formation waters. The volume of produced water increases with the maturity of the assets and the geothermal repurposing of Depleted Oil and gas wells could be an alternative to the mining closure. In the described transition scenario, the geothermal energy seems very promising because of its wide range of applications depending on the temperature of extracted fluids. This flexibility enables us to propose projects inspired by a circular economic vision considering the integration in the territory and social acceptance issues. In Italy, since 1985, 7246 wells have been drilled for hydrocarbon, of which 898 are located onshore with a productive or potentially productive operational status. This paper presents a preliminary investigation of Oil and gas fields located onshore in Italian territory based on the available information on temperature distribution at different depths. Then, taking into account the local energy demand, existing infrastructure, and land use of the territory, a conversion strategy for the producing wells is proposed for three case studies.
-
Coupling of energy conversion systems and wellbore heat exchanger in a Depleted Oil well
Geothermal Energy, 2016Co-Authors: Claudio Alimonti, D. Bocchetti, Daniela Berardi, E. SoldoAbstract:The conventional geothermal power plants use the reinjection wells mostly to avoid the depletion of the geothermal reservoir gathering in the underground of the produced brine. Nevertheless, reinjection operations entail high economic costs and some risks. An alternative is the extraction of the heat without geothermal fluids production, the wellbore heat exchanger. The goal of the present paper is the analysis of the power production of the wellbore heat exchanger (WBHX) in time and the comparison between two different conversion systems of the thermal energy into electrical: the organic ranking cycle (ORC) plant and the Stirling motor. The selected case study is the Oil field of Villafortuna Trecate, a medium enthalpy geothermal resource. The simulation results show a substantial decrease of the wellhead temperature in the first 6 months. After 1 year, the thermal power extracted with the WBHX is greater than 1.3 MW. The design parameters are 20 m3/h for the flow rate, outlet temperature 100.38 °C and the inlet temperature is 40 °C. The R-C318 has been selected as working fluid in the ORC plant: the net electrical power is 121 kW. The air is the working fluid in the Stirling motor: the evaluated net electrical power is 152 kW. The Stirling engine has an efficiency greater than 41 % compared to a system ORC.
William Ampomah - One of the best experts on this subject based on the ideXlab platform.
-
Assessment of CO2 trapping mechanisms in partially Depleted Oil-bearing sands
Fuel, 2020Co-Authors: Qian Sun, William Ampomah, Zhenxue Dai, Eusebius Junior Kutsienyo, Martin S. Appold, Benjamin Adu-gyamfi, Mohamed Reza SoltanianAbstract:Abstract The objective of this work is to evaluate various CO2 sequestration mechanisms occurring in the Morrow B Sandstone in the Farnsworth Unit. A history-matched numerical simulation model was created using extensive geological, petrophysical, and operational data collected from the field. The numerical model is competent to investigate the impact of residual, structural-stratigraphic, solubility, and mineral trapping mechanisms on the fluid transportation dynamics and petrophysical property variations. The model forecasts the field response of 20 years of WAG injections. Afterward, all wells were shut-in, and the reservoir was allowed to evolve for 1000 years to investigate the fate of injected CO2. In this paper, we assess the impacts of various trapping mechanisms on Oil recovery and CO2 storage efficacy. By analyzing the results reported from the numerical simulation model, the in-situ fluid composition and mineralogy changes are also investigated. More importantly, we seek to confirm the petrophysical property variations due to the CO2 injection with observations from laboratory measurements. The experiences gained from this study provide valuable insights regarding physiochemical storage induced by the CO2 injection activities and serve as a benchmark case for future CO2 enhanced Oil recovery (EOR) projects involving reactive solute transport.
-
co2 sequestration and enhanced Oil recovery at Depleted Oil gas reservoirs
Energy Procedia, 2017Co-Authors: Zhenxue Dai, William Ampomah, Feng Pan, Hari S. Viswanathan, Ting Xiao, Richard S. Middleton, Changbing Yang, Youqin Zhou, Wei Jia, Si Yong LeeAbstract:Abstract This paper presents a quantitative evaluation of the operational and technical risks of an active CO 2 -EOR project. A set of risk factor metrics is defined to post-process the Monte Carlo (MC) simulations for statistical analysis. The risk factors are expressed as measurable quantities that can be used to gain insight into project risk (e.g. environmental and economic risks) without the need to generate a rigorous consequence structure, which include (a) CO 2 injection rate, (b) net CO 2 injection rate, (c) cumulative CO 2 storage, (d) cumulative water injection, (e) Oil production rate, (f) cumulative Oil production, (g) cumulative CH4 production, and (h) CO 2 breakthrough time. The Morrow reservoir at the Farnsworth Unit (FWU) site, Texas, is used as an example for studying the multi-scale statistical approach for CO 2 accounting and risk analysis. A set of geostatistical-based MC simulations of CO 2 -Oil/gas-water flow and transport in the Morrow formation are conducted for evaluating the risk metrics. A response-surface-based economic model has been derived to calculate the CO 2 -EOR profitability for the FWU site with a current Oil price, which suggests that approximately 31% of the 1000 realizations can be profitable. If government carbon-tax credits are available, or the Oil price goes up or CO 2 capture and operating expenses reduce, more realizations would be profitable.
-
CO2 Sequestration and Enhanced Oil Recovery at Depleted Oil/Gas Reservoirs
Energy Procedia, 2017Co-Authors: Zhenxue Dai, William Ampomah, Feng Pan, Hari S. Viswanathan, Ting Xiao, Richard S. Middleton, Changbing Yang, Youqin Zhou, Wei Jia, Si Yong LeeAbstract:Abstract This paper presents a quantitative evaluation of the operational and technical risks of an active CO 2 -EOR project. A set of risk factor metrics is defined to post-process the Monte Carlo (MC) simulations for statistical analysis. The risk factors are expressed as measurable quantities that can be used to gain insight into project risk (e.g. environmental and economic risks) without the need to generate a rigorous consequence structure, which include (a) CO 2 injection rate, (b) net CO 2 injection rate, (c) cumulative CO 2 storage, (d) cumulative water injection, (e) Oil production rate, (f) cumulative Oil production, (g) cumulative CH4 production, and (h) CO 2 breakthrough time. The Morrow reservoir at the Farnsworth Unit (FWU) site, Texas, is used as an example for studying the multi-scale statistical approach for CO 2 accounting and risk analysis. A set of geostatistical-based MC simulations of CO 2 -Oil/gas-water flow and transport in the Morrow formation are conducted for evaluating the risk metrics. A response-surface-based economic model has been derived to calculate the CO 2 -EOR profitability for the FWU site with a current Oil price, which suggests that approximately 31% of the 1000 realizations can be profitable. If government carbon-tax credits are available, or the Oil price goes up or CO 2 capture and operating expenses reduce, more realizations would be profitable.
-
Optimization of CO 2 -EOR Process in Partially Depleted Oil Reservoirs
All Days, 2016Co-Authors: William Ampomah, Robert Balch, Reid B. Grigg, Martha Cather, R. A. Will, S. Y. LeeAbstract:Abstract This paper presents an optimization methodology for CO2 enhanced Oil recovery in partially Depleted reservoirs. A field-scale compositional reservoir flow model was developed for assessing the performance history of a CO2 flood and optimizing Oil production and CO2 storage in the Farnsworth field unit (FWU), Ochiltree County, Texas. A geological framework model constructed from geophysical, geological and engineering data acquired from FWU was used for the reservoir modeling. A laboratory fluid analysis was tuned to an equation of state and subsequently used to predict the thermodynamic minimum miscible pressure (MMP). An initial history calibration of primary, secondary and tertiary recovery are conducted as the basis for the study. After a good match was realized, an optimization model with proxy was constructed with an objective function that maximized both Oil recovery and CO2 storage. Experimental design was used to link uncertain parameters to the objective function. A reduced order proxy model was necessary to reduce computational cost. Control variables considered in this study included: CO2 purchase, recycled CO2, water alternating gas cycle and ratio, infill wells and bottomhole pressure of injectors and producers. Polynomial response surface methodology was used to create the proxy model based on training simulations. This involved an iterative process until a validated surrogate model was achieved. A sensitivity analysis was first conducted to ascertain which of these control variables to include in the reduced order model. A genetic algorithm using a mixed-integer capability optimization approach was employed to determine the optimum developmental strategy to maximize both Oil recovery and CO2 storage. The proxy model reduced the computational cost significantly. The validation of the reduced order model ensured accuracy in the dynamic modeling results. The prediction outcome showed the robustness and reliability of the genetic algorithm in optimizing Oil recovery and CO2 storage. The reservoir modeling approach used in this study showed an improved way of optimizing Oil production and CO2 storage within partially Depleted Oil reservoirs such as FWU. This study serves as a benchmark for potential CO2–EOR projects in the Anadarko basin and/or geologically similar basins throughout the world.
-
Compositional Simulation of CO2 Storage Capacity in Depleted Oil Reservoirs
All Days, 2015Co-Authors: William Ampomah, Robert Balch, Reid B. Grigg, Zhenxue Dai, Feng PanAbstract:Abstract The Farnsworth Unit (FWU) of Ochiltree County, Texas operated by Chaparral Energy L.L.C. is the site of a CO2-EOR project using anthropogenic CO2. The Southwest Regional Partnership on Carbon Sequestration (SWP), sponsored by the Department of Energy's National Energy Technology Laboratory, is using this project to monitor CO2 injection and movement in the field to determine CO2 storage potential in Depleted Oil reservoirs. The field was discovered in 1955 with estimated initial Oil in place of about 120 MMBO. The target reservoir is the Pennsylvanian-aged Upper Morrow sandstone, locally termed the Morrow "B" sandstone. CO2 flooding was initiated by Chaparral Energy in December 2010. This paper describes a compositional simulation of CO2 storage in a Depleted Oil reservoir. Mechanisms considered for CO2 storage include structural/stratigraphic trapping, dissolution in formation water and Oil, and residual trapping. A high resolution geological model constructed from geological, geophysical and engineering data from FWU was used for the study. FWU has no recorded Oil-water contact. The model was first calibrated to the reservoir's primary and secondary recovery history performance as a benchmark for the study. Several models were constructed and the storage capacity was analyzed as a function of injection volume, time and pressure. Numerical simulation results show that with over 25 years of WAG injection, 75% of the CO2 was sequestered. Afterwards wells were shut-in to monitor the storage. Significant amount of stored CO2 was dissolved in remaining Oil, contributing to enhanced Oil recovery from the tertiary stage of the field operations. Supercritical phase CO2 mass within the reservoir compared to CO2 dissolved in formation water was dependent on CO2 injection rate. Residual trapping contribution was significant when hysteresis was modeled. Pressure, volume of reservoir fluid present, and cap rock integrity and optimized WAG injection strategies were significant parameters to determine long-term CO2 storage capacity within FWU.
Srikanta Mishra - One of the best experts on this subject based on the ideXlab platform.
-
Application of a physics-based lumped parameter model to evaluate reservoir parameters during CO2 storage
Journal of Petroleum Exploration and Production Technology, 2020Co-Authors: Samin Raziperchikolaee, Srikanta MishraAbstract:Abstract Evaluating reservoir performance could be challenging, especially when available data are only limited to pressures and rates from Oil field production and/or injection wells. Numerical simulation is a typical approach to estimate reservoir properties using the history match process by reconciling field observations and model predictions. Performing numerical simulations can be computationally expensive by considering a large number of grids required to capture the spatial variation in geological properties, detailed structural complexity of the reservoir, and numerical time steps to cover different periods of Oil recovery. In this work, a simplified physics-based model is used to estimate specific reservoir parameters during CO2 storage into a Depleted Oil reservoir. The governing equation is based on the integrated capacitance resistance model algorithm. A multivariate linear regression method is used for estimating reservoir parameters (injectivity index and compressibility). Synthetic scenarios were generated using a multiphase flow numerical simulator. Then, the results of the simplified physics-based model in terms of the estimated fluid compressibility were compared against the simulation results. CO2 injection data including bottom hole pressure and injection rate were also gathered from a Depleted Oil reef in Michigan Basin. A field application of the simplified physics-based model was presented to estimate above-mentioned parameters for the case of CO2 storage in a Depleted Oil reservoir in Michigan Basin. The results of this work show that this simple lumped parameter model can be used for a quick estimation of the specific reservoir parameters and its changes over the CO2 injection period.
-
Application of a physics-based lumped parameter model to evaluate reservoir parameters during CO_2 storage
Journal of Petroleum Exploration and Production Technology, 2020Co-Authors: Samin Raziperchikolaee, Srikanta MishraAbstract:Evaluating reservoir performance could be challenging, especially when available data are only limited to pressures and rates from Oil field production and/or injection wells. Numerical simulation is a typical approach to estimate reservoir properties using the history match process by reconciling field observations and model predictions. Performing numerical simulations can be computationally expensive by considering a large number of grids required to capture the spatial variation in geological properties, detailed structural complexity of the reservoir, and numerical time steps to cover different periods of Oil recovery. In this work, a simplified physics-based model is used to estimate specific reservoir parameters during CO_2 storage into a Depleted Oil reservoir. The governing equation is based on the integrated capacitance resistance model algorithm. A multivariate linear regression method is used for estimating reservoir parameters (injectivity index and compressibility). Synthetic scenarios were generated using a multiphase flow numerical simulator. Then, the results of the simplified physics-based model in terms of the estimated fluid compressibility were compared against the simulation results. CO_2 injection data including bottom hole pressure and injection rate were also gathered from a Depleted Oil reef in Michigan Basin. A field application of the simplified physics-based model was presented to estimate above-mentioned parameters for the case of CO_2 storage in a Depleted Oil reservoir in Michigan Basin. The results of this work show that this simple lumped parameter model can be used for a quick estimation of the specific reservoir parameters and its changes over the CO_2 injection period.
-
New correlations for CO_2-Oil solubility and viscosity reduction for light Oils
Journal of Petroleum Exploration and Production Technology, 2016Co-Authors: Taylor Hall Barclay, Srikanta MishraAbstract:This paper presents the development of new empirical correlations for (1) CO_2 solubility in dead Oil and (2) Oil viscosity reduction ratio due to CO_2 saturation. These correlations are specifically developed for light Oils, i.e., with Oil gravities less than 0.9 (greater than 26° API). The new correlations are developed to be simple equations and dependent only on reservoir temperature and pressure while maintaining a relatively high level of accuracy. The new correlations developed in this work can be used as a tool for better performance evaluation of CO_2 injection into Depleted Oil fields and/or CO_2 sequestration.
-
New correlations for CO2-Oil solubility and viscosity reduction for light Oils
Journal of Petroleum Exploration and Production Technology, 2016Co-Authors: Taylor Hall Barclay, Srikanta MishraAbstract:This paper presents the development of new empirical correlations for (1) CO2 solubility in dead Oil and (2) Oil viscosity reduction ratio due to CO2 saturation. These correlations are specifically developed for light Oils, i.e., with Oil gravities less than 0.9 (greater than 26° API). The new correlations are developed to be simple equations and dependent only on reservoir temperature and pressure while maintaining a relatively high level of accuracy. The new correlations developed in this work can be used as a tool for better performance evaluation of CO2 injection into Depleted Oil fields and/or CO2 sequestration.
-
Estimating CO2-EOR Potential and Co-sequestration Capacity in Ohio's Depleted Oil Fields
Energy Procedia, 2014Co-Authors: Srikanta Mishra, Jared Hawkins, Taylor Hall Barclay, Meghan HarleyAbstract:Abstract The goal of this project is to develop process understanding and evaluate technical and economic feasibility of CO2 utilization and storage in Ohio. Our focus will be on Depleted Oil fields in the Clinton sandstone in eastern Ohio at depths ranging from 3400 to 5000 ft and the Knox dolomite in North-Central Ohio at depths ranging from 3000 to 8000 ft. These fields appear to be promising candidates for CO2-assisted EOR because of poor primary recovery efficiency that leaves behind ∼80-90% original Oil in place. However, a systematic assessment of enhanced recovery and co-sequestration potential in these under-pressured low- permeability Depleted Oil fields does not appear to have been undertaken – which is the focus of this research project. This paper describes ongoing activities in the areas of source-sink matching, production history assessment, reservoir characterization and fluid property characterization, as well as plans for reservoir simulation.
Zhenxue Dai - One of the best experts on this subject based on the ideXlab platform.
-
Assessment of CO2 trapping mechanisms in partially Depleted Oil-bearing sands
Fuel, 2020Co-Authors: Qian Sun, William Ampomah, Zhenxue Dai, Eusebius Junior Kutsienyo, Martin S. Appold, Benjamin Adu-gyamfi, Mohamed Reza SoltanianAbstract:Abstract The objective of this work is to evaluate various CO2 sequestration mechanisms occurring in the Morrow B Sandstone in the Farnsworth Unit. A history-matched numerical simulation model was created using extensive geological, petrophysical, and operational data collected from the field. The numerical model is competent to investigate the impact of residual, structural-stratigraphic, solubility, and mineral trapping mechanisms on the fluid transportation dynamics and petrophysical property variations. The model forecasts the field response of 20 years of WAG injections. Afterward, all wells were shut-in, and the reservoir was allowed to evolve for 1000 years to investigate the fate of injected CO2. In this paper, we assess the impacts of various trapping mechanisms on Oil recovery and CO2 storage efficacy. By analyzing the results reported from the numerical simulation model, the in-situ fluid composition and mineralogy changes are also investigated. More importantly, we seek to confirm the petrophysical property variations due to the CO2 injection with observations from laboratory measurements. The experiences gained from this study provide valuable insights regarding physiochemical storage induced by the CO2 injection activities and serve as a benchmark case for future CO2 enhanced Oil recovery (EOR) projects involving reactive solute transport.
-
co2 sequestration and enhanced Oil recovery at Depleted Oil gas reservoirs
Energy Procedia, 2017Co-Authors: Zhenxue Dai, William Ampomah, Feng Pan, Hari S. Viswanathan, Ting Xiao, Richard S. Middleton, Changbing Yang, Youqin Zhou, Wei Jia, Si Yong LeeAbstract:Abstract This paper presents a quantitative evaluation of the operational and technical risks of an active CO 2 -EOR project. A set of risk factor metrics is defined to post-process the Monte Carlo (MC) simulations for statistical analysis. The risk factors are expressed as measurable quantities that can be used to gain insight into project risk (e.g. environmental and economic risks) without the need to generate a rigorous consequence structure, which include (a) CO 2 injection rate, (b) net CO 2 injection rate, (c) cumulative CO 2 storage, (d) cumulative water injection, (e) Oil production rate, (f) cumulative Oil production, (g) cumulative CH4 production, and (h) CO 2 breakthrough time. The Morrow reservoir at the Farnsworth Unit (FWU) site, Texas, is used as an example for studying the multi-scale statistical approach for CO 2 accounting and risk analysis. A set of geostatistical-based MC simulations of CO 2 -Oil/gas-water flow and transport in the Morrow formation are conducted for evaluating the risk metrics. A response-surface-based economic model has been derived to calculate the CO 2 -EOR profitability for the FWU site with a current Oil price, which suggests that approximately 31% of the 1000 realizations can be profitable. If government carbon-tax credits are available, or the Oil price goes up or CO 2 capture and operating expenses reduce, more realizations would be profitable.
-
CO2 Sequestration and Enhanced Oil Recovery at Depleted Oil/Gas Reservoirs
Energy Procedia, 2017Co-Authors: Zhenxue Dai, William Ampomah, Feng Pan, Hari S. Viswanathan, Ting Xiao, Richard S. Middleton, Changbing Yang, Youqin Zhou, Wei Jia, Si Yong LeeAbstract:Abstract This paper presents a quantitative evaluation of the operational and technical risks of an active CO 2 -EOR project. A set of risk factor metrics is defined to post-process the Monte Carlo (MC) simulations for statistical analysis. The risk factors are expressed as measurable quantities that can be used to gain insight into project risk (e.g. environmental and economic risks) without the need to generate a rigorous consequence structure, which include (a) CO 2 injection rate, (b) net CO 2 injection rate, (c) cumulative CO 2 storage, (d) cumulative water injection, (e) Oil production rate, (f) cumulative Oil production, (g) cumulative CH4 production, and (h) CO 2 breakthrough time. The Morrow reservoir at the Farnsworth Unit (FWU) site, Texas, is used as an example for studying the multi-scale statistical approach for CO 2 accounting and risk analysis. A set of geostatistical-based MC simulations of CO 2 -Oil/gas-water flow and transport in the Morrow formation are conducted for evaluating the risk metrics. A response-surface-based economic model has been derived to calculate the CO 2 -EOR profitability for the FWU site with a current Oil price, which suggests that approximately 31% of the 1000 realizations can be profitable. If government carbon-tax credits are available, or the Oil price goes up or CO 2 capture and operating expenses reduce, more realizations would be profitable.
-
Compositional Simulation of CO2 Storage Capacity in Depleted Oil Reservoirs
All Days, 2015Co-Authors: William Ampomah, Robert Balch, Reid B. Grigg, Zhenxue Dai, Feng PanAbstract:Abstract The Farnsworth Unit (FWU) of Ochiltree County, Texas operated by Chaparral Energy L.L.C. is the site of a CO2-EOR project using anthropogenic CO2. The Southwest Regional Partnership on Carbon Sequestration (SWP), sponsored by the Department of Energy's National Energy Technology Laboratory, is using this project to monitor CO2 injection and movement in the field to determine CO2 storage potential in Depleted Oil reservoirs. The field was discovered in 1955 with estimated initial Oil in place of about 120 MMBO. The target reservoir is the Pennsylvanian-aged Upper Morrow sandstone, locally termed the Morrow "B" sandstone. CO2 flooding was initiated by Chaparral Energy in December 2010. This paper describes a compositional simulation of CO2 storage in a Depleted Oil reservoir. Mechanisms considered for CO2 storage include structural/stratigraphic trapping, dissolution in formation water and Oil, and residual trapping. A high resolution geological model constructed from geological, geophysical and engineering data from FWU was used for the study. FWU has no recorded Oil-water contact. The model was first calibrated to the reservoir's primary and secondary recovery history performance as a benchmark for the study. Several models were constructed and the storage capacity was analyzed as a function of injection volume, time and pressure. Numerical simulation results show that with over 25 years of WAG injection, 75% of the CO2 was sequestered. Afterwards wells were shut-in to monitor the storage. Significant amount of stored CO2 was dissolved in remaining Oil, contributing to enhanced Oil recovery from the tertiary stage of the field operations. Supercritical phase CO2 mass within the reservoir compared to CO2 dissolved in formation water was dependent on CO2 injection rate. Residual trapping contribution was significant when hysteresis was modeled. Pressure, volume of reservoir fluid present, and cap rock integrity and optimized WAG injection strategies were significant parameters to determine long-term CO2 storage capacity within FWU.