For 'slow' scenarios 1 and 2, the net amount of CO₂ injected (equal to CO₂ delivered for EOR) at each EOR field is distributed in time by assuming that each field is developed in six phases

<p><strong>Figure 7.</strong> For 'slow' scenarios 1 and 2, the net amount of CO₂ injected (equal to CO₂ delivered for EOR) at each EOR field is distributed in time by assuming that each field is developed in six phases. The six phases at each field are started at different times in order to approximate a constant need for CO₂ delivery that closely matches the approximately constant rate of CO₂/yr captured at three base load coal-fired generation units.</p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80% of the oil within five years). Upon applying a CO₂ emissions penalty of 60$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

The operating profits (all revenues from CO₂ and electricity sales minus all operating costs) for each scenario for all electricity generators in ERCOT show a considerable jump for the 'CO₂ emissions penalty' scenarios because of the assumption that consumers will not lower consumption at higher electricity prices

<p><strong>Figure 5.</strong> The operating profits (all revenues from CO₂ and electricity sales minus all operating costs) for each scenario for all electricity generators in ERCOT show a considerable jump for the 'CO₂ emissions penalty' scenarios because of the assumption that consumers will not lower consumption at higher electricity prices.</p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80% of the oil within five years). Upon applying a CO₂ emissions penalty of 60$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

Both scenarios 3 and 4 have very similar total CO₂ emissions captured from the 21 EGUs at 13 coal-fired power plants with CO₂ capture

<p><strong>Figure 11.</strong> Both scenarios 3 and 4 have very similar total CO₂ emissions captured from the 21 EGUs at 13 coal-fired power plants with CO₂ capture.</p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80% of the oil within five years). Upon applying a CO₂ emissions penalty of 60$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

The CO₂ emissions from the ERCOT coal fleet (a) and total ERCOT electric grid (b) are different for each scenario

<p><strong>Figure 4.</strong> The CO₂ emissions from the ERCOT coal fleet (a) and total ERCOT electric grid (b) are different for each scenario. (a) The emissions from the scenario-specific coal-fired plants are highest for scenarios 3 and 4 that, by definition, include more coal-fired power plants. (b) To conceptualize the quantity of CO₂ captured in each scenario, we show two baseline results for comparison in which no CO₂ is captured. 'Baseline: no emissions penalty, no sales price, no CO₂ capture' compares to scenarios 1 and 3 in which there is no emissions penalty. 'Baseline: $60/tCO₂ emissions penalty with no CO₂ capture' estimates the emissions from ERCOT generators when an emissions penalty exists but no generators have CO₂ capture.</p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

In the 'fast' scenarios 3 and 4, the net amount of CO₂/yr injected (equal to CO₂/yr delivered for EOR) at each EOR field over time is front-loaded as if all wells begin operations within the first 3 years of the analysis period

<p><strong>Figure 9.</strong> In the 'fast' scenarios 3 and 4, the net amount of CO₂/yr injected (equal to CO₂/yr delivered for EOR) at each EOR field over time is front-loaded as if all wells begin operations within the first 3 years of the analysis period.</p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80% of the oil within five years). Upon applying a CO₂ emissions penalty of 60$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

(a) The EOR oil production follows the delivered quantity of CO₂

<p><strong>Figure 8.</strong> (a) The EOR oil production follows the delivered quantity of CO₂. The oil price taken from the EIA AEO 2011 increases over time from 85$/BBL in year 1–124$/BBL in year 20. (b) Over the 20-year span of the modeled scenarios 1 and 2 the total CO₂ emissions captured from the three coal-fired EGUs is approximately equal to that needed for EOR in the ten oil fields.</p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80% of the oil within five years). Upon applying a CO₂ emissions penalty of 60$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

Capital and operating expenditures for each of the ten CO₂-EOR fields analyzed for the Texas Gulf Coast in $/BBL

<p><b>Table 2.</b>  Capital and operating expenditures for each of the ten CO₂-EOR fields analyzed for the Texas Gulf Coast in $/BBL. We assumed that EOR injection and production wells are drilled by side-tracking existing wells, so that capital costs are assumed at 50 </p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

Summary of system-wide economics of CCUS network ($2009 million)

<p><b>Table 4.</b>  Summary of system-wide economics of CCUS network ($2009 million). A 10$ kWh⁻¹; industrial; residential). </p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80% of the oil within five years). Upon applying a CO₂ emissions penalty of 60$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

Economic parameters and summarized costs for calculating net present value (NPV) for each scenario

<p><b>Table 3.</b>  Economic parameters and summarized costs for calculating net present value (NPV) for each scenario. All dollars in $2009. </p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p

The pipeline network for the <em>slow oil production scenarios</em> consists of approximately 540 miles of pipe of various diameters from 8 to 20 in

<p><strong>Figure 1.</strong> The pipeline network for the <em>slow oil production scenarios</em> consists of approximately 540 miles of pipe of various diameters from 8 to 20 in. The pipeline network for the <em>fast oil production scenarios</em> consists of approximately 1400 miles of pipe of various diameters from 8 to 20 in. Note that 4 segments (including the 'trunk' line connecting WA Parish and Tom O'Connor) are assumed to have 3 parallel 20 in pipelines, and 2 segments are assumed to have 2 parallel 20 in pipelines.</p> <p><strong>Abstract</strong></p> <p>This letter compares several bounding cases for understanding the economic viability of capturing large quantities of anthropogenic CO₂ from coal-fired power generators within the Electric Reliability Council of Texas electric grid and using it for pure CO₂ enhanced oil recovery (EOR) in the onshore coastal region of Texas along the Gulf of Mexico. All captured CO₂ in excess of that needed for EOR is sequestered in saline formations at the same geographic locations as the oil reservoirs but at a different depth. We analyze the extraction of oil from the same set of ten reservoirs within 20- and five-year time frames to describe how the scale of the carbon dioxide capture, utilization, and storage (CCUS) network changes to meet the rate of CO₂ demand for oil recovery. Our analysis shows that there is a negative system-wide net present value (NPV) for all modeled scenarios. The system comes close to breakeven economics when capturing CO₂ from three coal-fired power plants to produce oil via CO₂-EOR over 20 years and assuming no CO₂ emissions penalty. The NPV drops when we consider a larger network to produce oil more quickly (21 coal-fired generators with CO₂ capture to produce 80% of the oil within five years). Upon applying a CO₂ emissions penalty of 60$2009/tCO₂ to fossil fuel emissions to ensure that coal-fired power plants with CO₂ capture remain in baseload operation, the system economics drop significantly. We show near profitability for the cash flow of the EOR operations only; however, this situation requires relatively cheap electricity prices during operation.</p