Chad Augustine

An Estimate of the Near-Term Electricity-Generation Potential of Coproduced Water From Active Oil and Gas Wells

Co-produced water is water produced as a by-product during oil and gas production. Previous studies have estimated that 15-25 billion barrels of water are co-produced during oil and gas operations annually in the United States. Some well fields produce enough water at high enough temperatures that they could be used to produce electricity. Further, some have speculated that the total electricity generation potential of co-produced water resources in the United States could be tens of gigawatts. This study estimates the near-term market electricity generation potential of water produced as a by-product from active oil and gas operations. The study focuses on the near-term market potential of the coproduced resource and only considers co-production from existing oil and gas operations. A database consisting of oil and gas well data from across the United States was created by aggregating information from state oil and gas well databases. In all, oil and gas databases from 24 states determined to have significant oil and gas activity were aggregated, resulting in a co-production database containing records from 2.5 million wells, half a million of which were identified as active, producing wells. Then, a Geographic Information System (GIS) was developed to combine oil and gas well location, depth, and water production information with geothermal resource maps to estimate the co-produced water temperature. Coproduced water temperatures were estimated based on maps created from a separate database containing the bottom-hole temperature of 27,000 wells and from temperature-at-depth maps developed by the Southern Methodist University Geothermal Laboratory. Models were developed to calculate the power generation potential of the co-production resource based on the co-produced water volume and temperature estimates. A cut-off temperature for electricity production of 176° F (80° C) was assumed. Several scenarios were explored to determine the sensitivity of the resource potential estimate to assumptions and results from the study. Over 60% of active wells in the database were found to have estimated temperatures of less than 176° F (80° C). Nearly 20% of the active wells lack sufficient data (primarily well depth) to make a temperature estimate. Although the study indicates that there are a significant number of oil and gas operations with sufficient temperatures and co-produced water volumes that could potentially be utilized for electricity generation, it was concluded that the near-term market potential for the co-production resource as a whole is roughly 300 MWe. This estimate does not take into account practical operational factors such as a minimum power plant size, availability of cooling water or transmission, project economics, etc., that could further limit the number of sites that could be developed. The majority of the co-production resource potential is in Texas, which accounts for roughly two-thirds of the near-term electricity generation potential. Given the size of the Texas co-produced resource potential relative to the rest of the United States and that co-produced water data for Texas was based on reported re-injected water volumes, a more thorough study based on actual well data is recommended.

Global Value Chain and Manufacturing Analysis on Geothermal Power Plant Turbines

The global geothermal electricity market has significantly grown over the last decade and is expected to reach a total installed capacity of 18.4 GWe in 2021 (GEA, 2016). Currently, geothermal project developers customize the size of the power plant to fit the resource being developed. In particular, the turbine is designed and sized to optimize efficiency and resource utilization for electricity production; most often, other power plant components are then chosen to complement the turbine design. These custom turbine designs demand one-off manufacturing processes, which result in higher manufacturing setup costs, longer lead-times, and higher capital costs overall in comparison to largervolume line manufacturing processes. In contrast, turbines produced in standard increments, manufactured in larger volumes, could result in lower costs per turbine. This study focuses on analysis of the global supply chain and manufacturing costs for Organic Rankine Cycle (ORC) turboexpanders and steam turbines used in geothermal power plants. In this study, we developed a manufacturing cost model to identify requirements for equipment, facilities, raw materials, and labor. We analyzed three different cases 1) 1 MWe geothermal ORC turboexpander 2) 5 MWe ORC turboexpander and 3) 20 MWe geothermal steam turbine, and calculated the cost of manufacturing the major components, such as the impellers/blades, shaft/rotor, nozzles, inlet guide lanes, disks, and casings. Then we used discounted cash flow (DCF) analysis to calculate the minimum sustainable price (MSP). MSP is the minimum price that a company must sell its product for in order to pay back the capital and operating expenses during the plant lifetime (CEMAC, 2017). The results showed that MSP could highly vary between 893

2017 Annual Technology Baseline (ATB): Cost and Performance Data for Electricity Generation Technologies

/kW and 30

Hydrothermal flames: From phenomenological experimental demonstrations to quantitative understanding

/kW based on turbine size, standardization and volume of manufacturing. The analysis also showed that the economy of scale applies both to the size of the turbine and the number manufactured in a single run. Sensitivity analysis indicated these savings come largely from reduced labor costs for design and engineering and manufacturing setup.

Cost analysis of oil, gas, and geothermal well drilling

Each year since 2015, NREL has presented Annual Technology Baseline (ATB) in a spreadsheet that contains detailed cost and performance data (both current and projected) for renewable and conventional technologies. The spreadsheet includes a workbook for each technology. This spreadsheet provides data for the 2017 ATB. In this edition of the ATB, offshore wind power has been updated to include 15 technical resource groups. And, two options are now provided for representing market conditions for project financing, including current market conditions and long-term historical conditions. For more information, see https://atb.nrel.gov/.