SUMEER KALRA | University of Oklahoma (original) (raw)

Papers by SUMEER KALRA

All Days, Apr 17, 2014

Literature shows that there is a significant amount of natural gas available for enhanced recover... more Literature shows that there is a significant amount of natural gas available for enhanced recovery in the depleted reservoirs; at the same time, the depleted gas reservoirs are a proven storage facility for Carbon Dioxide (CO2) storage in terms of reservoir integrity. Conceptually, injecting CO2 into a depleted gas reservoir will not only potentially rejuvenalize the gas production, but will also store the greenhouse gas in a proven subsurface formation. Study on CO2 phase behavior in subsurface conditions shows that CO2 most likely will be in super-critical state which exhibits liquid-like density and gas-like viscosity. These properties are favorable in displacing natural gas reservoirs in volumetric and pore scale sweep efficiency. Using numerical reservoir simulation on a synthetic case with multiple scenarios, this paper identifies the most amenable characteristics of a reservoir for enhancing gas production by injecting CO2 and analyzes the parameters influencing this secondary recovery process. In the paper, reservoir depth, depletion pressure ratio, aquifer activity, inclination angle, reservoir heterogeneity with various permeability arrangement, injection rate, and producer bottomhole pressure will be studied on the synthetic model. Furthermore, this paper will quantify the amount of natural gas which can be produced and CO2 that can be stored in an ideal case using economic matrix. From this study, the ideal candidates for enhanced gas recovery by CO2 injection will be proposed based on simulation results, thus one can screen the available gas reservoirs for CO2 storage purpose and can quickly quantify the additional gas production from the secondary recovery.

Hydraulic fracturing has been applied as an effective method to increase gas production from shal... more Hydraulic fracturing has been applied as an effective method to increase gas production from shale formations; however, this method has also raised concerns about its adverse impacts on environment. For example, in the Marcellus shale formation, some measured radon-gas concentrations exceeded the safe standard. Therefore, it is important to quantitatively evaluate radon concentration from fractured wells. However, existing researches have not successfully conducted a systematic and predictive study on the relationship between shale gas production and radon concentration at the wellhead of a hydraulically fractured well. To address this issue and quantitatively determine the radon concentration, we present the mechanisms of radon-gas generation and releasing, and conducted numerical simulations on its transport process in the subsurface formation system. The concentration of radon in produced gas is related with the original sources where the natural gas is extracted. Radon, generated from the radium alpha decay process, is trapped in pore spaces before the reservoir development. With the fluid flowing through the subsurface network, released radon will move to surface with the produced streams such as natural gas and flowback water. Our study shows that the radon concentration at wellhead could be significant. Influential factors such as natural-fracture-network properties, formation petrophysical parameters, and fracture dimension are investigated with sensitivity studies through numerical simulations. Analysis results suggest that radon wellhead concentration is strongly related with production rate. Thus, careful production design and protection are necessary to reduce radon hazard regarding the public and environmental impact. mately 10% of pore volume (PV) consisted of pores with diameters less than 1.2 nm, 45% of PV was occupied by pores with

SPE Liquids-Rich Basins Conference - North America, 2017

The Mississippian-age Meramec Series is one of the primary producing intervals of the Sooner Tren... more The Mississippian-age Meramec Series is one of the primary producing intervals of the Sooner Trend in the Anadarko Basin of Canadian and Kingfisher (STACK) counties, Oklahoma and is currently among the most sought-after hydrocarbon plays in the US. It is a low permeability and low porosity play; therefore, understanding reservoir limits, fluid characterization, and petrophysical characterization are critical to development planning of these reservoirs. In this study, we establish an integrated workflow for multi-component fluid characterization, stimulation-region limits and hydraulic-fracture-dimension estimation, and apply the workflow to a study area of the Meramec interval in the STACK play of Oklahoma. First, rate transient analysis (RTA) is used to characterize porosity, permeability, fracture dimensions and drainage areas. Subsequently, an Equation-of-State (EOS) model is established for the study area spanning the liquids-rich zone to high Gas-Oil Ratio (GOR) region. The EOS...

Hydrocarbon resources from unconventional reservoirs, especially tight/shale plays, are changing ... more Hydrocarbon resources from unconventional reservoirs, especially tight/shale plays, are changing the North America's energy prospect. Single digit percentage of oil shale recovery with current best practices, leaves a large room for recovery improvement. While aqueous phase injection into tight formation is extremely challenging, other recovery techniques need to be evaluated and pilot tested for secondary recovery in oil shale reservoirs. Injecting Carbon Dioxide (CO2) into oil shale formations can potentially improve oil recovery. Furthermore, the large surface area in the organic rich shale could permanently store CO2 volume without jeopardizing the formation integrity.This work is a study on evaluating the effectiveness of CO2 enhanced oil shale recovery and shale formation CO2 sequestration capacity. The work identified the most favorable reservoir properties and operating envelop for field application of CO2-EOR in tight formations. A compositional reservoir simulator is u...

$Research paper thumbnail of Estimation of hydraulic fracture volume utilizing partitioning chemical tracer in shale gas formation$

Journal of Natural Gas Science and Engineering

Petroleum Science

Less than 10% of oil is usually recovered from liquid-rich shales and this leaves much room for i... more Less than 10% of oil is usually recovered from liquid-rich shales and this leaves much room for improvement, while water injection into shale formation is virtually impossible because of the extremely low permeability of the formation matrix. Injecting carbon dioxide (CO 2) into oil shale formations can potentially improve oil recovery. Furthermore, the large surface area in organicrich shale could permanently store CO 2 without jeopardizing the formation integrity. This work is a mechanism study of evaluating the effectiveness of CO 2-enhanced oil shale recovery and shale formation CO 2 sequestration capacity using numerical simulation. Petrophysical and fluid properties similar to the Bakken Formation are used to set up the base model for simulation. Result shows that the CO 2 injection could increase the oil recovery factor from 7.4% to 53%. In addition, petrophysical characteristics such as in situ stress changes and presence of a natural fracture network in the shale formation are proven to have impacts on subsurface CO 2 flow. A response surface modeling approach was applied to investigate the interaction between parameters and generate a proxy model for optimizing oil recovery and CO 2 injectivity. Keywords CO 2 EOR Á Tight formations Á Experimental design Á Response surface modeling Á Recovery of shale liquid Á CO 2 sequestration & Wei Tian

SPE Western Regional Meeting, 2016

SPE Western North American and Rocky Mountain Joint Meeting, 2014

Petroleum Science, Nov 2, 2017