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Carroll, Susan

Publications and source records attributed to Carroll, Susan.

At least 19 records
All sourcesNASA NTRSDOE OSTI
DOE OSTI2019

Understanding the role of reactive chemistry and transport on the permeability of carbonate carbon storage reservoirs

Geologic carbon storage remains a critical technology to mitigate climate change as the world strives towards a carbon-free economy. Both sandstone and carbonate reservoirs are primary targets for geologic storage, with depleted oil and gas reservoirs viewed as first adopters of the technology, especially those reservoirs using CO 2 to enhance hydrocarbon recovery. Our work focuses on carbonate reservoirs because new pore space and enhanced permeability are likely to result as CO 2 and reservoir brines partially dissolve carbonate minerals until equilibrium is reached, particularly in fields subjected to CO 2 - enhanced oil recovery targeted for long-term CO 2 storage. Estimating meaningful changes in porosity and permeability in carbonate oil fields has been an active area of research. This topic is especially complicated because the significant pore and mineral heterogeneities characteristic of carbonate reservoirs play an outsized role in controlling reaction-induced fluid transport.

58 GEOSCIENCES↗
DOE OSTI2018

Dynamic reduced order modelling (ROM) of chemical and mechanical processes in CO 2 -cement systems

Damaged wells pose a significant risk of leakage of reservoir fluids stored in a geological CO 2 storage site. The leaking CO 2 can react with well cement and alter its chemical, mechanical, and hydraulic properties. Recently, we have developed an experimentally-calibrated model that couples two-phase flow, reactive transport of brine, cement geochemistry, and geomechanics to predict the leakage of reservoir fluids through a fractured pathway in a cemented well (Iyer, et al. 2018, Iyer, et al. 2017, Walsh, et al. 2013, Walsh, et al. 2014, Walsh, et al. 2014)

58 GEOSCIENCES↗
DOE OSTI2018

Integrated Pre-Feasibility Assessment for a Northern Michigan Basin CarbonSAFE CO 2 Storage Complex

One of the key gaps in the critical path toward carbon capture and storage (CCS) deployment is the development of commercial-scale (50+ million metric tons carbon dioxide [CO2]) geologic storage sites for CO 2 from industrial sources. There has been relatively little effort by the private sector to identify and certify (i.e., regulatory permit) geologic storage sites that are capable of storing commercial-scale volumes of CO 2 , primarily because of the lack of immediate economic incentives. As a result, commercial-scale CO 2 sources that want to develop CCS projects face the risk of not finding a suitable saline storage site for their captured CO 2 . Carbon Storage Assurance Facility Enterprise (CarbonSAFE) is a U.S. Department of Energy (DOE)-sponsored effort to develop an integrated CCS storage complex constructed and permitted for operation in the 2025 timeframe over a series of sequential phases of development: Integrated CCS Pre-Feasibility, Storage Complex Feasibility, Site Characterization, and Permitting and Construction. Subject to availability of funds, a series of funding opportunity announcements (FOAs) are planned to accomplish this mission. This document describes a project that addresses DOE FOA-1584 Phase I: Integrated Carbon Capture and Storage (CCS) Pre-Feasibility. The objective of this project was to take the first step in developing an integrated commercial geologic CO 2 storage complex in the Northern Michigan Basin, herein referred to as the CarbonSAFE – Northern Michigan Basin (CS-NMB) storage complex. This includes demonstrating that the storage sites within the complex have the potential to store more than 50 million metric tons (MMT) of industrially-sourced CO 2 emissions safely, permanently and economically. To achieve the overall objective of the Phase I pre-feasibility study, FOA-1584 required three activities: • Perform a high-level technical sub-basinal evaluation to identify a potential storage complex with storage site(s), including a description of the geology and risks associated with the potential storage site; identify and evaluate potential CO 2 sources. • Develop a plan for the storage complex and storage site(s) including a strategy that would enable an integrated capture and storage project to be economically feasible and publicly acceptable. • Form a CCS coordination team capable of addressing regulatory, legislative, technical, public policy, commercial, financial, etc. challenges specific to commercial-scale deployment of the CO 2 storage project.

20 FOSSIL-FUELED POWER PLANTS↗
DOE OSTI2018

Assessment of the Area of Review and Leakage Impact for Site 7 using the NRAP-IAM-CCS Tool, Northern Michigan Basin-CarbonSAFE Phase 1 Pre-Feasibility Study

U.S. Environmental Protection Agency’s (EPA’s) Class VI regulations require owners or operators of carbon storage projects to determine an Area of Review (AoR) representative of project risk to underground sources of drinking water (USDWs). The AoR is an estimate of the project footprint and is used to develop monitoring plans to ensure protection of USDWs. In this syudy, the NRAP-IAM-CS software tool was applied to estimate the AoR and the leakage potential of legacy wells located within the AoR to impact groundwater quality at a carbon storage screening site for the NMB-CS, Phase 1 project. The NRAP-IAM-CS is a science-based toolset developed by the U.S. Department of Energy for quantitative risk assessment of geologic sequestration of carbon dioxide (CO 2 ) (Pawar et al., 2016). The toolset adopts a stochastic approach in which predictions include site uncertainties using storage reservoir, leakage scenario, and shallow groundwater impact reduced order models (ROMs). Risk-based analysis done using the NRAP-IAM-CS yielded an AoR that was comparable to estimates defined by the critical pressure needed move fluid from the reservoir to the overlying USDW through an open wellbore. The risk-based AoR was slightly smaller than that based on the critical pressure (234 km 2 compared to 269 km 2 ), because small fluxes did not impact groundwater quality. Leakage from two legacy wells located within the AoR should not impact groundwater quality over the 30-year injection period. Legacy Well 1 penetrates the simulated CO 2 plume and would require a permeability of 5 x 10 -12 m 2 (~5 Darcy) to impact groundwater quality after about 20 years of injection. Legacy Well 2 falls outside of the CO 2 plume footprint, where reservoir pressures are too small to generate large enough leakage flux to change groundwater quality even with well permeabilities as high as 5 x 10 -11 m 2 (~50 Darcy). This work represents one of the first applications of the NRAP toolset for the screening of potential CO 2 storage sites. The toolset provides a risk-based method of evaluating the AoR and the impact of CO 2 or brine leakage through legacy wells. The following recommendations will strengthen the use of probabilistic assessments for site selection and permitting of Class VI CO 2 injection wells.

12 MANAGEMENT OF RADIOACTIVE AND NON-RADIOACTIVE W↗
DOE OSTI2017

Application of the Aquifer Impact Model to support decisions at a CO 2 sequestration site

The National Risk Assessment Partnership (NRAP) has developed a suite of tools to assess and manage risk at CO 2 sequestration sites. The NRAP tool suite includes the Aquifer Impact Model (AIM), which evaluates the potential for groundwater impacts from leaks of CO 2 and brine through abandoned wellbores. There are two aquifer reduced-order models (ROMs) included with the AIM tool, a confined alluvium aquifer, and an unconfined carbonate aquifer. The models accept aquifer parameters as a range of variable inputs so they may have broad applicability. The generic aquifer models may be used at the early stages of site selection, when site-specific data is not available. Guidelines have been developed for determining when the generic ROMs might be applicable to a new site. This work considers the application of the AIM to predicting the impact of CO 2 or brine leakage were it to occur at the Illinois Basin Decatur Project (IBDP). Results of the model sensitivity analysis can help guide characterization efforts; the hydraulic parameters and leakage source term magnitude are more sensitive than clay fraction or cation exchange capacity. Sand permeability was the only hydraulic parameter measured at the IBDP site. More information on the other hydraulic parameters could reduce uncertainty in risk estimates. Some non-adjustable parameters are significantly different for the ROM than for the observations at the IBDP site. The generic ROMs could be made more useful to a wider range of sites if the initial conditions and no-impact threshold values were adjustable parameters.

29 ENERGY PLANNING, POLICY, AND ECONOMY↗
DOE OSTI2017

Chlorite, Biotite, Illite, Muscovite and Feldspar Dissolution Kinetics at Variable pH and Temperatures up to 280 deg C

Chemical reactions pose an important but poorly understood threat to EGS long-term success because of their impact on fracture permeability. This report summarizes the dissolution rate equations for layered silicates where data were lacking for geothermal systems. Here we report updated rate laws for chlorite (Carroll and Smith 2013), biotite (Carroll and Smith, 2015), illite (Carroll and Smith, 2014), and for muscovite. Also included is a spreadsheet with rate data and rate equations for use in reactive transport simulators.

15 GEOTHERMAL ENERGY↗
DOE OSTI2016

Merits of pressure and geochemical data as indicators of CO 2 /brine leakage into a heterogeneous, sedimentary aquifer

This study assesses the merits of pressure data and geochemical data as indicators of a combined CO 2 /brine leakage into a heterogeneous, sedimentary aquifer. We simulate the changes in three aquifer responses (pressure, total dissolved solids (TDS), and pH) due to CO 2 /brine leakage at an abandoned well with an uncertain location and hypothesize that these changes can only be observed from a single shallow monitoring well, mimicking the low density of observation wells for the considered aquifer. Specifically, detection likelihoods are calculated to describe how frequently pressure, TDS, and pH signals will coincide with a leak for observations made at different distances and times from the initiation of the CO 2 /brine leakage rate. The pressure signal gives a more spatially extensive signal than either TDS or pH, and pressure detection probabilities increase upstream of flow barriers (pressurizing-affect). The pH and TDS rebound down-stream of the flow barriers. Finally, when only considering the samples that experience the highest leakage volumes, there is a 50% likelihood of detecting a pressure change 400 m away at times ≥30 years. However, the TDS and pH detection likelihoods are <20% at 100 m distance for times ≥30 years.

58 GEOSCIENCES↗
DOE OSTI2016

Applicability of aquifer impact models to support decisions at CO 2 sequestration sites

The National Risk Assessment Partnership has developed a suite of tools to assess and manage risk at CO 2 sequestration sites. This capability includes polynomial or look-up table based reduced-order models (ROMs) that predict the impact of CO 2 and brine leaks on overlying aquifers. The development of these computationally-efficient models and the underlying reactive transport simulations they emulate has been documented elsewhere (Carroll et al., 2014a; Carroll et al., 2014b; Dai et al., 2014 ; Keating et al., 2016). Here in this paper, we seek to demonstrate applicability of ROM-based analysis by considering what types of decisions and aquifer types would benefit from the ROM analysis. We present four hypothetical examples where applying ROMs, in ensemble mode, could support decisions during a geologic CO 2 sequestration project. These decisions pertain to site selection, site characterization, monitoring network evaluation, and health impacts. In all cases, we consider potential brine/CO 2 leak rates at the base of the aquifer to be uncertain. We show that derived probabilities provide information relevant to the decision at hand. Although the ROMs were developed using site-specific data from two aquifers (High Plains and Edwards), the models accept aquifer characteristics as variable inputs and so they may have more broad applicability. We conclude that pH and TDS predictions are the most transferable to other aquifers based on the analysis of the nine water quality metrics (pH, TDS, 4 trace metals, 3 organic compounds). Guidelines are presented for determining the aquifer types for which the ROMs should be applicable.

54 ENVIRONMENTAL SCIENCES↗
DOE OSTI2014

Quantification of key long-term risks at CO₂ sequestration sites: Latest results from US DOE's National Risk Assessment Partnership (NRAP) Project

Risk assessment for geologic CO₂ storage including quantification of risks is an area of active investigation. The National Risk Assessment Partnership (NRAP) is a US-Department of Energy (US-DOE) effort focused on developing a defensible, science-based methodology and platform for quantifying risk profiles at geologic CO₂ sequestration sites. NRAP has been developing a methodology that centers round development of an integrated assessment model (IAM) using system modeling approach to quantify risks and risk profiles. The IAM has been used to calculate risk profiles with a few key potential impacts due to potential CO₂ and brine leakage. The simulation results are also used to determine long-term storage security relationships and compare the long-term storage effectiveness to IPCC storage permanence goal. Additionally, we also demonstrate application of IAM for uncertainty quantification in order to determine parameters to which the uncertainty in model results is most sensitive.

54 ENVIRONMENTAL SCIENCES↗