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Vikara, Derek

Publications and source records attributed to Vikara, Derek.

At least 19 records
All sourcesNASA NTRSDOE OSTI
DOE OSTI2025

FECM/NETL Offshore CO2 Saline Storage Cost Model

The FECM/NETL Offshore CO2 Saline Storage Cost Model (CO2_S_COM_Offshore) estimates costs for a CO2 storage project in an offshore saline formation or reservoir. It is applicable for storage projects located on the Outer Continental Shelf of the Gulf of America. The purpose is to model the costs associated with a project, using simplified geo-engineering equations to calculate reservoir values needed to determine costs (such as CO2 plume area and number of injection wells). To use the model, change any of the inputs, which are always in orange cells, to the values you desire. Although there are numerous values that can be changed, the values expected to be of most interest have input cells on the 'Key_Inputs' sheet. Last update: 5/2/2025; Version 1.1 corrects bug in reservoir thickness calculations.

Carbon storage↗
DOE OSTI2024

Carbon storage cost modeling for the offshore Gulf of Mexico

Groundbreaking for geologic carbon storage (GCS) projects in the offshore Gulf of Mexico is imminent, and there is great interest in utilizing this region for GCS projects. Offshore saline reservoirs provide a significant and accessible resource for GCS. However, conducting GCS in the offshore environment will pose distinct challenges pertaining to site selection, operations, infrastructure use, and monitoring compared to operating onshore that ultimately affect technoeconomic assessment of offshore GCS projects. Carbon storage and transport costs are critical to project developers looking to deploy carbon storage in the offshore environment. We present CO2_S_COM_Offshore, a model developed by the National Energy Technology Laboratory (NETL) as a screening-level offshore saline GCS cost modeling tool. Based on NETL’s widely used CO2_S_COM cost model for onshore saline CS, CO2_S_COM_Offshore enables technoeconomic analysis of GCS in offshore areas. This model comprehensively incorporates multiple facets of offshore GCS projects, from regional evaluation and site selection to permitting, transport, operations, monitoring, site closure, and decommissioning. In general, the model can explore the cost implications for potential offshore GCS project(s) by enabling the user to change several project operational and financial attribute configurations. Key inputs include offshore storage formation options, CO2 injection rate and duration, infrastructure types, monitoring intensity, project financing, and post-injection site care duration. Supporting cost algorithms within CO2_S_COM_Offshore were compiled utilizing S&P Global’ s QUE$TORTM cost estimation software alongside a variety of open-source scientific literature. In addition to reviewing key model components, we discuss several sensitivity analyses, input variabilities, and results on analysis of break-even CO2 price required by a project based on different regulation/policy and operational scenarios for the offshore Gulf of Mexico. These results indicate the value of modeling offshore GCS specifically, and the potential of offshore GCS within a decarbonization value chain. Presented at the 41st USAEE/IAEE North American Conference, 3-6 November 2024, Baton Rouge, LA, United States.

Mark-Moser, Mackenzie K.↗
DOE OSTI2024

Basin-scale study of CO 2 storage in stacked sequence of geological formations

Commercial scale decarbonization through carbon capture and storage may likely involve many CO 2 storage projects located in close proximity. The close proximity could raise concerns over caprock integrity associated with reservoir pressure buildup and interference among adjacent projects. Commercial-scale injection will also require large prospective CO 2 storage resource and high injectivity in the targeted storage formations. To accommodate the need for both large resource and high injectivity, project operators could consider injecting CO 2 into a stacked sequence of formations. This analysis investigates the benefits of injecting CO 2 into a vertically stacked sequence of saline formations, over injecting the same amount of CO 2 into a single saline formation, in addressing these challenges. Our analysis shows that injecting into the stacked sequence mitigates the extent of pressure buildup among the stacked formations, while still achieving the same or greater target CO 2 storage volumes. Among cases modeled, the resulting pressure buildup front is most reduced when each storage site distributes injection volumes over several wells, each of which injects a portion of the total CO 2 mass across the stacked sequence. This favorable case not only results in the smallest CO 2 aerial footprint, but also shows the largest reduction in the pressure buildup at the top of perforation at the injection wells (upwards of approximately 46% compared to the single-formation storage), the result of which is crucial to maintain caprock integrity. This analysis provides insights into required decision-making when considering multi-project deployment in a shared basin.

42 ENGINEERING↗
DOE OSTI2024

Dynamic modeling studies of basin-scale pressure interference and CO 2 plume evolution in multi-well geologic CO 2 storage

This research employs numerical modeling to analyze how CO 2 plumes and pressure fronts evolve when CO 2 is injected into a single storage formation from multiple projects located in proximity. Here, this analysis also evaluates the extent to which injection well spacing alleviates pressure buildup in the absence of active pressure management tactics. The simulation approach was based on a single, homogenous saline aquifer in which CO 2 injection occurs under a one-injector baseline case and several multi-well cases where well spacing varies. Analysis results show that the extent of pressure buildup is in the range of tens or a few hundreds of kilometers and contingent upon the defining pressure buildup demarcating the front edge. For the geological setting evaluated in this paper, our analysis suggests that without active basin pressure management strategies, commercial-scale projects would likely need to be sited far apart to avoid pressure interference from one another. Analysis results show the radius of CO 2 plume varies approximately from 2 to 3 km from injection wells (each injecting 1 Mt/year for 30 years) depending on cases and modeling parameters assumed. Given the pressure interference, this paper thus draws attention to the importance of greater coordination among storage operators and regulatory stakeholders. Because this analysis assumes a very specific geologic setting, this exploratory analysis bears further investigations across other geologic scenarios.

42 ENGINEERING↗
DOE OSTI2024

SMART Task 6: Evaluation of the Costs of Geologic CO2 Storage for the Illinois Basin Decatur Project Site Using the NRAP/SMART Technoeconomic and Liability Evaluation for Storage (TALES) Model

This is a presentation featuring an analysis related to SMART Task 6 in which CO2 storage costs are presented. The National Energy Technology Laboratory has developed the NRAP/SMART Technoeconomic and Liability Evaluation for Storage (TALES) model to provide quantitative cost-based insights to support developers planning CO2 injection and storage projects. TALES calculates the revenues, costs, and financial performance of candidate CO2 saline storage project based on site-specific activity costs and financial parameters. TALES is being integrated as a module pertaining to storage cost as part of the broader SMART Visualization and Decision Support Platform (SVDSP). In this study, the TALES model was applied using real activity cost data associated with the development and operations at the Illinois Basin Decatur Project (IBDP) CO2 storage project site. Scenario analysis was implemented in which crucial operational and cost attributes were varied and the associated cost implications observed. Key results data and project cost summary metrics like first-year breakeven price of CO2 ($/tonne) and net present value (NPV) are presented in similar fashion to how they will appear in the SVDSP.

Vikara, Derek↗
DOE OSTI2024

NRAP Task 5: Preliminary Evaluation of the Cost of Responding to a Hypothetical Leakage Scenario Using the NRAP/SMART TALES Model and other NRAP Tools

Poster presentation illustrating the use of tools developed as part of Task 5 of Phase 3 of NRAP to estimate the technical performance and costs of implementing remedial responses to address a leak of fluid out of the storage formation at a CO2 saline storage project. Presented at the 2024 FECM - NETL Carbon Management Research Project Review Meeting, 5-9 August, 2024, Pittsburgh, PA.

Morgan, David↗
DOE OSTI2024

Quality Guidelines for Energy System Studies: Carbon Dioxide Transport and Storage Costs in NETL Studies

Transport, storage, and combined T&S costs are reported in this guideline as first-year break even (FYBE) costs in real 2023 dollars per metric ton (tonne) (2023$/tonne). These FYBE costs are from the perspective of a CO 2 pipeline project owner and/or a CO 2 saline storage project owner, and represent a minimum price the owner(s) can charge a CO 2 capture project owner over 30 operating years to transport and/or store a tonne of CO 2 and remain economically viable.

29 ENERGY PLANNING, POLICY, AND ECONOMY↗
DOE OSTI2024

Techno-economic Model and Analysis for Hydrogen (H2) Pipeline Transportation

Presentation at the 9th ELAEE (Latin American Energy Economics Meeting) July 28th – 30th, 2024 in PUC-Rio, Rio de Janeiro, Brazil. The presentation highlights the FECM/NETL Hydrogen Pipeline Cost Model (H2_P_COM). The model estimates costs for transporting gaseous hydrogen in a pipeline from a source, such as a hydrogen production facility, to a final destination which may be a user of the hydrogen or a distribution center where hydrogen in the pipeline is diverted to multiple end users.

Cunha, Luciane↗
DOE OSTI2024

FECM/NETL Natural Gas with Hydrogen Pipeline Cost Model (2024): Description and User’s Manual

This is the user’s manual for The FECM/NETL Natural Gas with Hydrogen Pipeline Cost Model (NG-H2_P_COM) that estimates costs for transporting gaseous hydrogen with natural gas in a pipeline from a source, such as a hydrogen production facility, to a final destination which may be a user of the hydrogen and natural gas or a distribution center where hydrogen in the pipeline with natural gas is diverted to multiple end users. This user’s manual provides two main functions. First, the detailed statement describes the equations and algorithms that are used by the model to calculate technical quantities (such as blend hydrogen percentage, reuse percentage of the pipeline and stations, the pipe diameter size and length needed to transport a user-specified hydrogen with natural gas rate in a specified distance) and engineering-economic quantities (such as capital costs, operating costs, and cash flows). Second, the document is a user’s manual for the model that describes the procedures the user must follow to configure and setup the model, run the model, analyze the results, and visualize the outcomes. Such details offer user a quick and handy way to utilize the model for their application and decision making. The model can be accessed at this URL: https://www.netl.doe.gov/energy-analysis/details?id=cf3f6564-3c55-4aa5-b712-7160e558d9f6. The Model Results and Comparative Analysis can be accessed here: https://www.netl.doe.gov/energy-analysis/details?id=83862799-a28c-4944-a809-90b7e23d4af6.

03 NATURAL GAS↗
DOE OSTI2024

FECM/NETL Hydrogen Pipeline Cost Model (2024): Description and User’s Manual

The FECM/NETL Hydrogen Pipeline Cost Model (H2_P_COM) estimates costs for transporting gaseous hydrogen in a pipeline from a source, such as a hydrogen production facility, to a final destination which may be a user of the hydrogen or a distribution center where hydrogen in the pipeline is diverted to multiple end users. This document provides two main functions. First, the document describes the equations and algorithms that are used by the model to calculate technical quantities (such as the minimum inner pipe diameter needed to transport a user-specified H 2 mass flow rate a specified distance) and engineering-economic quantities (such as capital costs, operating costs, and cash flows). Second, the document is a user’s manual for the model that describes the procedures the user must follow to run the model. The model can be accessed at this URL: https://www.netl.doe.gov/energy-analysis/details?id=db897190-8e26-40b1-9535-ee78ac934193

08 HYDROGEN↗
DOE OSTI2024

Modeling the Cost of Onshore CO2 Pipeline Transport and Onshore CO2 Saline Storage

This paper describes the FECM/NETL CO2 Transport Cost Model (CO2_T_COM), a technoeconomic model of CO2 transport by pipeline, and the FECM/NETL CO2 Saline Storage Cost Model (CO2_S_COM), a technoeconomic model of storage of CO2 in a deep, subsurface saline formation. The results of applying CO2_T_COM to calculate break-even CO2 prices to transport CO2 at different mass flow rates and different distances are presented. Similarly, CO2_S_COM is used to calculate the break-even CO2 price for storing CO2 in 314 potential storage formations across the US. These break-even prices are used to construct cost-supply curves for CO2 storage which are presented on a national and regional basis. CO2_T_COM and CO2_S_COM are the most comprehensive open source technoeconomic models available for analyzing CO2 pipeline transport and CO2 saline storage. To be presented at the SPE?AAPG/SEG Carbon Capture Utilization and Storage Conference in Houston, TX, March 11-13, 2024.

Morgan, David↗
DOE OSTI2024

Modeling Cost of Offshore Carbon Storage in Saline Reservoirs

Poster presentation to the AAPG-SEG-SPE CCUS 2024 Conference. Offshore saline reservoirs provide a significant and accessible resource for geologic carbon storage (CS). The offshore environment requires distinct approaches to site selection, operations, monitoring, and risk that affect the technoeconomic assessment of offshore CS projects. The National Energy Technology Laboratory (NETL) has developed a CS cost model for offshore saline reservoirs known as CO2_S_COM_Offshore. Based on NETL’s widely used CO2_S_COM cost model for onshore saline CS, CO2_S_COM_Offshore enables technoeconomic analysis of CS in offshore areas. This model comprehensively incorporates multiple facets of offshore CS projects, from regional evaluation and site selection to permitting, transport, operations, monitoring, site closure, and decommissioning. Developed to model cost for offshore United States (US) Exclusive Economic Zones, aspects of this model can be adapted to international projects. Presented at the SPE/AAPG/SEG Carbon Capture Utilization and Storage Conference in Houston, TX, March 11-13, 2024.

Mark-Moser, Mackenzie K.↗
DOE OSTI2023

NETL’s Techno-Economic Modeling Resources for Analyzing Decarbonization Strategies Using CCUS

NETL has developed techno-economic models to evaluate the performance characteristics and cost drivers for elements of the carbon capture, utilization, and storage (CCUS/CCS) value chain: CO2 capture, CO2 pipeline transport, CO2 saline storage, and oil production and CO2 storage using CO2 enhanced oil recovery (EOR). These tools can be used individually to evaluate the economic opportunity for specific CCUS components, or they can be used in tandem to assess integrated CCUS systems. An overview and high-level description of the transport and storage models is presented in a poster along with useful outputs that can be generated with each.

Morgan, David↗