FundOpp_DE-FOA-0003606_Amd_000003.pdf

Financial Assistance Notice of Funding Opportunity Part 1

Department of Energy (DOE) Office of Fossil Energy and Carbon Management Improving Efficiency, Reliability, and Flexibility of Coal-Based Power Plants Notice of Funding Opportunity Number: DE-FOA-0003606

Application due: January 23, 2026 (no later than 5:00 p.m. ET)

MODIFICATIONS

Modification No. Date Description of Modification

000001

11/17/2025

Clarifications to Section(s) IV.C.2. Summary of Application Requirements and IV.C.3. Technical Volume

000002

12/02/2025

Clarifications to Section(s) II.D.1. DOE and Non-DOE FFRDCs as a Subrecipient and Section IV.A. Use and Disclosure of Application

Information

000003

1/6/2026

Clarifications to Sections III.B, D., and E. regarding Topic Area

Requirements and extend the Application Due Date.

All modifications to the Notice of Funding Opportunity (NOFO) are

HIGHLIGHTED in the body of the NOFO.

Table of Contents

Contents

Before You Begin Navigating the Notice of Funding Opportunity

I. Basic Information A. Key Facts

1. Funding Details

2. Period of Performance

B. Executive Summary C. Teaming Partner List D. Agency Contact Information

II. Eligibility A. Eligible Applicants

1. Domestic Entities

2. Foreign Entity Participation

3. Performance of Work in the United States

4. Ineligible Participants

B. Limitation on Number of Applications Eligible for Review C. Cost Sharing

1. Cost Share Requirements

2. Unallowable Cost Share Sources, NOFO Specific

D. FFRDC Eligibility Criteria

1. DOE and Non-DOE FFRDCs as a Subrecipient

III. Program Description A. Program Purpose B. Program Goals and Objectives C. Expected Performance Goals D. Topic Areas E. Applications Specifically Not of Interest F. Statement of Substantial Involvement G. Statutory Authority

IV. Application Content and Form A. Use and Disclosure of Application Information B. Summary C. Application Content Requirements

1. Covered Individual Definition, Designation, and Responsibility

2. Summary of Application Requirements

3. Technical Volume

4. Resumes for Research and Development (R&D)

5. Current and Pending (Other) Support

D. Funding Restrictions

1. Buy America Preference for Infrastructure Projects

V. Submission Requirements and Deadlines A. Required Registrations

1. Unique Entity Identifier (UEI) and System for Award Management (SAM)

2. eXCHANGE

3. Grants.gov Registration

B. Application Package

1. eXCHANGE

C. Submission Date and Times D. Intergovernmental Review

VI. Application Review Information A. Standards for Application Evaluation B. Responsiveness Review C. Review Criteria

1. Compliance Criteria

2. Technical Review Criteria

D. Other Selection Factors

VII. Selection and Award Notices

VIII. Award Administration Information A. Post-Award Requirements and Administration

1. Real Property and Equipment

2. Program Down-Select

3. Rights in Technical Data

4. Cost Share Payment

5. Invoice Review and Approval

6. Energy Data eXchange (EDX) Requirements

B. Questions and Support

1. Questions

2. Support

IX. Other Information A. Acronyms

Before You Begin

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Before You Begin Navigating the Notice of Funding Opportunity To reduce the burden on applicants in the Notice of Funding Opportunity (NOFO) process and limit the length of the NOFO information requests DOE has separated the NOFO into two parts.

The NOFO Part 1 describes the specific DOE programmatic goals and evaluation criteria, eligibility, and other components that are specific to each funding opportunity. The NOFO Part 2 includes the fixed DOE requirements that generally do not change from NOFO to NOFO, including standard information for the application phase, expectations for award negotiations, and post-award requirements. Applicants must review both the NOFO Part 1 and the NOFO Part 2 prior to applying. To facilitate navigation, you will find links throughout this document to additional information found in Part 2.

There are several required one-time actions applicants must take before applying to this NOFO. Some of these actions may take several weeks, so it is vital applicants build in enough time to complete them.

Failure to complete these actions could interfere with application or negotiation deadlines or the ability to receive an award if selected. If you have previously completed the necessary registrations, make sure your registration is active and up to date. All registrations are free. Please refer to NOFO Part 2, Get Registered, for additional information.

This announcement is published in conjunction with NOFO Part 2 Version 3.0

Section I: Basic Information

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I. Basic Information A. Key Facts

Issuing Agency Department of Energy, Office of Fossil Energy and Carbon

Management (FECM)

Funding Opportunity Title

Improving Efficiency, Reliability, and Flexibility of Coal-Based Power Plants

Announcement Type Initial

Funding Opportunity Number

DE-FOA-0003606

Funding Instrument Cooperative Agreements

Assistance Listing Number

81.089

Funding Opportunity Description

The purpose of this NOFO is to seek applications for projects to design, implement, test and validate three compelling opportunities (here-in-after “topic areas”) for strategic refurbishment/retrofit of existing coal power plants, providing a path for rapid and cost-effective restoration of stability to the nation’s bulk power system while supporting the nation’s industrial and energy security priorities by enabling coal powered systems to provide reliable, secure, and affordable electricity delivered in the near term at scale. Successful projects will lead to the implementation of transformational technologies that will significantly improve the efficiency, effectiveness, costs, emissions reductions, and environmental performance of coal and natural gas use.

Program Goals & Objective(s)

The Office of Fossil Energy and Carbon Management funds research, development and demonstration activities targeting technologies that can significantly improve efficiency, effectiveness, costs, and performance of coal and natural gas use in power, manufacturing and industrial facilities. These investments will foster U.S. energy dominance, continue energy security, and enable U.S.

competitiveness in global markets.

KEY DATES

Notice of Funding Opportunity Issue Date:

October 31st , 2025

Application Deadline:

January 23rd , (no later than 5:00 p.m. ET)

Anticipated Selection Notification Date:

May 2026

Anticipated Award Date:

July 2026

Estimated Period of Performance:

Phase I: July 2026

– July 2027

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Topic Areas • Topic Area 1: Development and Implementation of Advanced

Wastewater Systems

• Topic Area 2: Engineering and Implementation of Dual Firing

Retrofits

• Topic Area 3: Development and Testing of Natural Gas

Cofiring Systems Eligible Applicants • Domestic Entities (Institutes of higher education; for-profit entities; non-profit entities; state and local government entities and Indian Tribes

• DOE FFRDC’s and non-DOE FFRDCs and Federal Research Agencies eXCHANGE URL and Helpdesk

NETL eXCHANGE: Funding Opportunities NETL-ExchangeSupport@hq.doe.gov

1. Funding Details

Approximate total available NOFO funding: $100,000,000 federal share

Topic Area 1: Development and Implementation of Advanced Wastewater Systems

• Approximate total available federal funding: $50 million

• Approximate number of awards: 0-5

• Approximate federal dollar amount of individual awards: $400,000 to $50 million total across three phases with a competitive downselect between Phase I and Phase II:

o Phase I: $400,000 federal share o Phase II + Phase III: up to $48 million federal share

• Minimum cost share required: Phase I and Phase II: 20%; Phase III: 50%

• Approximate total award project period (inclusive of all Phases): Up to 60 months

• Anticipated length of phases: 12 months (Phase I), 12 months (Phase II), and up to 36 months

(Phase III)

Topic Area 2: Engineering and Implementation of Dual Firing Retrofits

• Approximate total available federal funding: $25 million

• Approximate number of awards: 0-5

• Approximate federal dollar amount of individual awards: $400,000 to $25 million total across three phases with a competitive downselect between Phase I and Phase II:

o Phase I: $400,000 federal share o Phase II + Phase III: up to $23 million federal share

• Minimum cost share required: Phase I and Phase II: 20%; Phase III: 50%

• Approximate total award (inclusive of all Phases): Up to 60 months

• Anticipated length of phases: 12 months (Phase I), 12 months (Phase II), and up to 36 months

(Phase III) https://netl-exchange.energy.gov/Default.aspx mailto:NETL-ExchangeSupport@hq.doe.gov

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Topic Area 3: Development and Testing of Natural Gas Cofiring Systems

• Approximate total available federal funding: $25 million

• Approximate number of awards: 0-5

• Approximate federal dollar amount of individual awards: $400,000 to $25 million total across three phases with a competitive downselect between Phase I and Phase II:

o Phase I: $400,000 federal share o Phase II + Phase III: up to $23 million federal share

• Minimum cost share required: Phase I and Phase II: 20%; Phase III: 50%

• Approximate total award (inclusive of all Phases): Up to 60 months

• Anticipated length of phases: 12 months (Phase I), 12 months (Phase II), and up to 36 months

(Phase III)

2. Period of Performance DOE anticipates making awards comprised of multiple phases. If applicable, project continuation will be contingent upon DOE’s downselect and Go/No-Go decision processes. For a complete list and more information on the Go/No-Go review, see the NOFO Part 2, Award Administration Information. Funding for all phases, including the initial phase, is not guaranteed.

FECM anticipates Phase I awards will run for 12 months, but work must be completed within the first 9 months to allow for the down select process, anticipated to take up to 3 months. FECM anticipates a 12 month period of performance for Phase II, with an associated Go/No-Go Decision process/review between Phase II and Phase III. FECM anticipates up to 36 months for Phase III activities.

B. Executive Summary The United States is confronting an urgent energy capacity crisis. DOE’s 2025 Resource Adequacy Report (DOE/GR-2025-001)1 confirmed that the rapid retirement of firm thermal generation has outpaced the deployment of replacement resources capable of delivering necessary grid services. These challenges are especially acute in regions with constrained transmission and sustained load growth. In January 2025, Executive Order 14156, Declaring a National Energy Emergency, directed DOE and other Federal agencies to use their full and lawful authority to preserve and restore statutory authority to ensure reliable, affordable, and secure generation capacity.2

The operational strain created by the increasing penetration of intermittent renewables, insufficient compensation in markets and onerous environmental compliance costs, has forced thermal units to cycle beyond their designed parameters, accelerating wear and raising the risk of forced outages and blackouts. This reliability emergency coincides with surging demand from national defense installations, semiconductor fabrication plants, Artificial Intelligence (AI) data centers, critical mineral processing, and industrial re-shoring, all of which require access to power.

1 U.S. Department of Energy, Resource Adequacy Report: Evaluating the Reliability and Security of the United States Electric Grid (July 7, 2025), https://www.energy.gov/sites/default/files/2025-07/DOE Final EO Report %28FINAL JULY 7%29.pdf.

2 See Exec. Order No. 14156 of Jan. 20, 2025, Declaring a National Energy Emergency, 90 Fed. Reg. 8433 (Jan.

29, 2025), https://www.federalregister.gov/documents/2025/01/29/2025-02003/declaring-a-national-energy-emergency.

https://www.energy.gov/sites/default/files/2025-07/DOE%20Final%20EO%20Report%20%28FINAL%20JULY%207%29.pdf https://www.energy.gov/sites/default/files/2025-07/DOE%20Final%20EO%20Report%20%28FINAL%20JULY%207%29.pdf https://www.energy.gov/sites/default/files/2025-07/DOE%20Final%20EO%20Report%20%28FINAL%20JULY%207%29.pdf https://www.federalregister.gov/documents/2025/01/29/2025-02003/declaring-a-national-energy-emergency https://www.federalregister.gov/documents/2025/01/29/2025-02003/declaring-a-national-energy-emergency https://www.federalregister.gov/documents/2025/01/29/2025-02003/declaring-a-national-energy-emergency

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Coal-fired facilities, long central to U.S. energy security, are affordable, reliable, secure, and uniquely positioned to deliver near-term reliability at scale. Specifically, the United States possesses a substantial fleet of nearly 200 gigawatts (GW) of coal-fired power plants currently in operation. A significant portion of this capacity, approximately 100 GW, presents a compelling opportunity for strategic refurbishment, providing a path for rapid and cost-effective restoration of stability to the nation’s bulk power system while supporting the nation’s industrial and energy security priorities.

C. Teaming Partner List DOE is compiling a Teaming Partner List to facilitate the formation of project teams for this NOFO. The Teaming Partner List allows organizations that may wish to participate on a project to express their interest to other applicants and explore potential partnerships.

The Teaming Partner List will be available on eXCHANGE and will be regularly updated to reflect new teaming partners who provide their organization’s information.

SUBMISSION INSTRUCTIONS: View the Teaming Partner List by visiting the eXCHANGE homepage and clicking on “Teaming Partners” within the left-hand navigation pane. This page allows users to view published Teaming Partner Lists. To join the Teaming Partner List, submit a request within eXCHANGE.

Select the appropriate Teaming Partner List from the drop-down menu, and fill in the following information: Investigator Name, Organization Name, Organization Type, Topic Area, Background and Capabilities, Website, Contact Address, Contact Email, and Contact Phone.

DISCLAIMER: By submitting a request to be included on the Teaming Partner List, the requesting organization consents to the publication of the above-referenced information. By facilitating the Teaming Partner List, DOE is not endorsing, sponsoring, or otherwise evaluating the qualifications of the individuals and organizations that are identifying themselves for placement on this Teaming Partner List.

DOE will not pay for the provision of any information, nor will it compensate any applicants or requesting organizations for the development of such information.

D. Agency Contact Information Office of Fossil Energy and Carbon Management U.S. Department of Energy 1000 Independence Ave SW Washington, D.C. 20585

For questions relating to this specific NOFO, please send emails to DE-FOA-0003606@netl.doe.gov.

mailto:DE-FOA-0003606@netl.doe.gov

Section II: Eligibility

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II. Eligibility To be considered for substantive evaluation, an applicant’s submission must meet the criteria set forth below. If the application does not meet these eligibility requirements, it will be considered ineligible and removed from further evaluation and ineligible for any award. DOE will not make eligibility determinations for potential applicants prior to the date on which applications to this NOFO must be submitted. The decision whether to apply in response to this NOFO lies solely with the applicant. The information included here is specific to eligibility requirements for this NOFO. For eligibility requirements applicable to all NOFOs, please consult the NOFO Part 2, Eligibility.

A. Eligible Applicants To be considered for substantive evaluation, an applicant’s submission must meet the criteria set forth below. If the application does not meet these eligibility requirements, it will be considered ineligible and removed from further evaluation.

1. Domestic Entities

Domestic entities are eligible to apply as recipients or subrecipients. The following types of domestic entities are eligible to participate as a recipient or subrecipient of this NOFO:

• Institutions of higher education; (See Title 20 U.S.C. § 1001 for the definition);

• For-profit organization;

• Nonprofit organization;

• State and local governmental entities; and

• Indian Tribes, as defined in section 4 of the Indian Self-Determination and Education Assistance

Act, 25 U.S.C. § 53043

To qualify as a domestic entity, the entity must be organized, chartered, or incorporated (or otherwise formed) under the laws of a particular state or territory of the United States or under the laws of the United States; have majority domestic ownership and control; and have a physical place of business in the United States.

Participant Limitations Participation of the following entities are limited as follows.

• DOE FFRDCs4 are eligible to apply for funding as a subrecipient but are not eligible to apply as a recipient.

3 “Indian Tribe,” for the purposes of this NOFO and as defined in in section 4 of the Indian Self-Determination and Education Assistance Act (25 U.S.C. § 5304), means any Indian tribe, band, nation, or other organized group or community, including any Alaska Native village or regional or village corporation as defined in or established pursuant to the Alaska Native Claims Settlement Act (85 Stat. 688) [43 U.S.C. § 1601, et seq.], which is recognized as eligible for the special programs and services provided by the United States to Indians because of their status as Indians.

4 FFRDCs are public-private partnerships that conduct research for the U.S. Government. A listing of FFRDCs can be found at http://www.nsf.gov/statistics/ffrdclist/.

https://uscode.house.gov/view.xhtml?req=(title%3A25%20section%3A5304%20edition%3Aprelim) https://uscode.house.gov/statutes/pl/92/203.pdf#%3A%7E%3Atext%3D688%20PUBLIC%20LAW%2092-203-DEC.%2018%2C%201971%20%5B85%20STAT.%2Cand%20for%20other%20purposes.%20Alaska%20Native%20Claims%20Settlement https://uscode.house.gov/statutes/pl/92/203.pdf#%3A%7E%3Atext%3D688%20PUBLIC%20LAW%2092-203-DEC.%2018%2C%201971%20%5B85%20STAT.%2Cand%20for%20other%20purposes.%20Alaska%20Native%20Claims%20Settlement https://uscode.house.gov/view.xhtml?req=(title%3A43%20section%3A1601%20edition%3Aprelim) http://www.nsf.gov/statistics/ffrdclist/

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• Non-DOE FFRDCs are eligible to participate as a subrecipient but are not eligible to apply as a recipient.

• Federal agencies and instrumentalities (other than DOE) are eligible to participate as a subrecipient but are typically not eligible to apply as a recipient.

• NETL is not eligible for award under this announcement and may not be proposed as a subrecipient on another entity’s application. An application that includes NETL as a recipient or subrecipient will be considered non-responsive.

2. Foreign Entity Participation

In general, foreign entities are not eligible to apply as either a recipient or subrecipient. In limited circumstances, DOE may approve a waiver to allow a foreign entity to participate as a recipient or subrecipient.

A foreign entity may submit an application to this NOFO, but the application must be accompanied by an explicit written waiver request. Likewise, if the applicant seeks to include a foreign entity as a subrecipient, the applicant must submit a separate explicit written waiver request in the application for each proposed foreign subrecipient. Please see NOFO Part 2, Application Content Requirements for the requirements for submission of a foreign entity waiver request. The applicant does not have the right to appeal DOE’s decision concerning a waiver request.

3. Performance of Work in the United States

All work for the awards under this NOFO must be performed in the United States. To request a waiver of this requirement, the applicant must submit an explicit waiver request in the application. Absent an approved waiver, such costs will not be allowable under the award. The NOFO Part 2, Application Content Requirements lists the requirements for submission of a foreign work waiver request.

4. Ineligible Participants

The following entities are ineligible for participation in this NOFO as a recipient, subrecipient, or subcontractor.

• In accordance with 2 CFR 200.214, entities banned from doing business with the U.S.

government such as entities debarred, suspended, or otherwise excluded from or ineligible for participating in federal programs.

• Entities identified on Department of the Treasury Office of Foreign Assets Control Treasury’s Sanctions Program Specially Designated Nationals list are prohibited from doing business with the United States government and are not eligible. See OFAC - Sanctions List Service (treas.gov).

• Nonprofit organizations described in Section 501(c)(4) of the Internal Revenue Code of 1986 that engaged in lobbying activities after December 31, 1995, are not eligible to apply for funding.

Entity of Concern Prohibition Entities of Concern are prohibited from participating in projects selected under this NOFO (see NOFO Part 2, Eligibility, Other Eligibility Information, Entity of Concern Prohibition section for details and definitions).

https://sanctionslist.ofac.treas.gov/Home/SdnList

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B. Limitation on Number of Applications Eligible for Review An entity may submit more than one application to this NOFO, provided that each application describes a unique, scientifically distinct project.

C. Cost Sharing Applicants are expected to follow through on estimated cost share commitments proposed in their applications if selected for award negotiations. Please refer to the NOFO Part 2, Eligibility for more information on Cost Sharing.

1. Cost Share Requirements

The cost share must be at least 20% of the total project costs5 for Phase I and Phase II research and development projects6 and 50% of the total project costs for Phase III demonstration and commercial application projects.7

2. Unallowable Cost Share Sources, NOFO Specific

There are no unallowable cost share sources specific to this announcement. Refer to NOFO Part 2, Eligibility--Cost Sharing, Unallowable Cost Share Sources for unallowable cost share sources applicable to all NOFOs.

D. FFRDC Eligibility Criteria

1. DOE and Non-DOE FFRDCs as a Subrecipient As long as they have no conflict, DOE and non-DOE FFRDCs may be proposed as a subrecipient on another entity’s application subject to the following guidelines:

Authorization for non-DOE FFRDCs The federal agency sponsoring the FFRDC must authorize in writing the use of the FFRDC on the proposed project and this authorization must be submitted with the application. The use of a FFRDC must be consistent with its authority under its award.

Authorization for DOE FFRDCs The cognizant Contracting Officer for the FFRDC must authorize in writing the use of the FFRDC on the proposed project and this authorization must be submitted with the application prior to any award. The use of a FFRDC must be consistent with the contractor’s authority under its award.

5 Total project costs are the sum of the government share, including FFRDC costs if applicable, and the recipient share of project costs.

6 Energy Policy Act of 2005, Pub. L. 109-58, sec. 988. Also see 2 CFR 200.306 and 2 CFR 910.130 for additional cost sharing requirements.

7 Energy Policy Act of 2005, Pub. L. 109-58, sec. 988. Also see 2 CFR 200.306 and 2 CFR 910.130 for additional cost sharing requirements.

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Funding, Cost Share, and Subaward with FFRDCs The recipient and FFRDC are responsible for entering into an appropriate subaward that will govern, among other things, the funding of the FFRDC portion of the work from the recipient under its DOE award. Such an agreement must be fully executed prior to the FFRDC starting work directly allocable to the FA award. The DOE funding office will provide funding for the DOE FFRDC or non-DOE FFRDC, participating as a sub awardee under the DOE financial assistance award to the recipient.

The applicant should prepare the budgets using rates appropriate for funding the FFRDCs through subawards. The applicant’s cost share requirement will be based on the total cost of the project, including the applicant’s, the subrecipient’s, and the FFRDC’s portions of the project.

Responsibility The recipient will be the responsible authority regarding the settlement and satisfaction of all contractual and administrative issues, including but not limited to disputes and claims arising out of any agreement between the recipient and the FFRDC.

Limit on FFRDC Effort The FFRDC effort, in aggregate, shall not exceed 15% of the total project cost.88

8 Total project cost is the sum of the government share, including FFRDC costs if applicable, and the recipient share of project costs.

Section III: Program Description

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III. Program Description A. Program Purpose FECM is issuing this Notice of Funding Opportunity (NOFO). Under Sec. 961 of the Energy Policy Act of 2005, FECM is responsible for carrying out research, development, demonstration, and commercial application programs in fossil energy with the goal of improving the efficiency, effectiveness, and environmental performance of fossil energy production, upgrading, conversion, and consumption.

42 U.S.C. 16291. Additionally, under Sec. 962 of the Energy Policy Act of 2005, FE is responsible for carrying out the Carbon Capture Technology Program, under which DOE may take into consideration “increasing the performance of coal electric generation facilities and natural gas electric generation facilities” and “reducing the use, and managing the discharge, of water in power plant operations.”

42 U.S.C. 16292(b)(3)(A) and (C)(ii). The Topic Areas (TA) of this NOFO align with these authorities and support the development of transformational technologies that will significantly improve the efficiency, effectiveness, costs, emissions reductions, and environmental performance of coal and natural gas use, including in manufacturing and industrial facilities.

Activities executed through this NOFO are intended to facilitate the development of transformational wastewater management systems, dual firing retrofits, and natural gas cofiring systems for coal-fired facilities with a compelling opportunity for strategic refurbishment. Achieving this goal would help enable a rapid and cost-effective path to ensuring affordable, reliable, secure power at scale to address the surging energy demand from national defense installations, semiconductor fabrication plants, AI data centers, critical mineral processing, and industrial re-shoring, all of which require access to power.

B. Program Goals and Objectives The fossil power generation industry has observed a shift from coal toward natural gas firing, largely driven by increasing costs to maintain and operate the Nation’s aging fleet of coal-fired facilities coupled with sustained low natural gas prices. Managing the significant amounts of coal combustion residuals (CCRs) generated by combusting coal and other regulated waste streams often represent a significant operating and maintenance cost of coal-fired electricity generation. However, technologies capable of economically treating regulated waste streams in a manner that enables enhanced recovery of water and other commercial byproducts present an opportunity to improve the economic competitiveness of coal-fired power plants. Moreover, increasing the fuel flexibility of coal-fired electricity generators to enable rapid fuel switching between coal and natural gas provides an attractive option to maintain the many favorable system reliability and resiliency attributes that coal-fired electricity generators provide while at the same time addressing the need for fossil-fueled (coal and natural gas) electricity generation to adapt to rapidly evolving market demands.

Prepare the existing coal fleet for future Carbon Capture Utilization and Storage (CCUS) retrofit. The CCUS conceptual design should include an overview of proposed CO2 capture strategies, project integration approaches, preliminary specifications and costs, key design features to maximize economic viability, and a justification for the recommended technology. If applicable, specific plans for utilization, injection strategies, and the associated economic benefit should also be discussed. The outcome is a baseline concept suitable for Pre-FEED and FEED studies.

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The purpose of this NOFO is to seek applications for projects to design, implement, test and validate three strategic opportunities for refurbishment/retrofit of existing coal power plants. TA’s under this NOFO include:

• TA1: Development and Implementation of Advanced Wastewater Management Systems –

This TA is focused on the development, engineering, and implementation of transformational wastewater management systems capable of cost-effective recovery of water and other value-added byproducts from wastewater streams. Technologies under this topic area are anticipated to facilitate the development of transformational wastewater management systems for improved environmental performance by reducing the use and managing the discharge of water in power plant operations supported by a CCUS conceptual design to reduce CO2 emissions while providing additional revenue opportunities via enhanced oil and/or natural gas recovery (EOR/EGR). Successful implementation will allow coproduction of value-added products to diversify coal plant operators’ revenue streams. Concepts that include carbon utilization are preferred over approaches that solely implement carbon capture and storage. The CCUS concept should consider water management strategies, relevant laws and regulations governing key aspects of CCUS integration such as water processing, solvent regeneration, equipment cooling, and process integration.

• TA2: Engineering and Implementation of Dual Firing Retrofits – This TA is focused on engineering, design, and implementation of retrofit systems for existing coal plants that enable automatic switching between coal and natural gas without compromising critical operational parameters. Technologies advanced under this topic area are anticipated to facilitate the development of transformational systems for providing increased fuel flexibility to enable transition between coal-firing and gas-firing in power plant operations supported by a CCUS conceptual design to reduce CO2 emissions while providing additional revenue opportunities via enhanced oil and/or natural gas recovery (EOR/EGR). Successful implementation will allow reduction of reduce emissions and optimization of while optimizing operational costs, providing enhanced competitiveness during periods of fuel price volatility. Concepts that include carbon utilization are preferred over approaches that solely implement carbon capture and storage.

• TA3: Development and Testing of Natural Gas Cofiring Systems – This TA is focused on development, engineering, and implementation of transformational coal-natural gas co-firing systems and system components (including highly fuel flexible burner designs coupled with advanced control systems) supported by a CCUS conceptual design to reduce CO2 emissions while providing additional revenue opportunities via enhanced oil and/or natural gas recovery (EOR/EGR). Technologies advanced under this topic area that are intended to provide a low cost retrofit option that can enables coal plants to maximize gas co-firing capability while optimizing and emissions and minimizing reduction with minimal efficiency penalties. Successful implementation will enhance the economic viability of coal plants while at the same time achieving improved environmental performance. Concepts that include carbon utilization are preferred over approaches that solely implement carbon capture and storage.

Once successful, projects resulting from this NOFO are anticipated to support a path for rapid and cost-effective restoration of stability to the nation’s bulk power system while at the same time supporting the nation’s industrial and energy security priorities enabling improvements in coal powered system performance, efficiency, and cost of electricity.

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This NOFO seeks applications that advance technologies currently at Technology Readiness Level (TRL) 7 (Full-scale, similar (prototypical) system demonstrated in relevant environment) or higher and projects applying to this NOFO should have sufficient technical detail to support a minimum TRL 7. Successful projects are expected to validate technology cost and performance through operational testing at commercially relevant scale such that subject technologies will achieve TRL 8 (Actual system completed and qualified through test and demonstration) or higher.

The NOFO will be carried out in three phases, with a down-select between Phase I and Phase II and a go/no-go decision point between Phase II and Phase III.

Phase I (Project Definition and Preliminary Design and Engineering) will be aimed at supporting recipients’ efforts to secure team commitments (including host sites and recipient cost share for Phase II and Phase III), complete a preliminary front-end engineering and design study (pre-As) including cost estimate and schedule for design, construction, and operation, and complete an environmental information volume (EIV).

Projects selected for Phase II (Final Engineering and Detailed Design) will secure a commitment from an Engineering Procurement Contractor (EPC), complete a Front-End Engineering Design (FEED) study, secure construction/operation cost share funding, and complete the National Environmental Policy Act (NEPA) process required for demonstration and validation.

Project(s) that meet the go/no-go decision point criteria to proceed onto Phase III (Technology Implementation and Validation) will support implementation and testing at coal facilities. Testing and validation of operating systems is necessary to reduce the technical and financial risk associated with the adoption of a new technology in the marketplace. While the scale is dependent on the type of technology being deployed, applicants to this NOFO should have already experienced technical success of the integrated components to the extent that the next step is a commercial demonstration. The projects supported by this NOFO will be used to demonstrate the scalability and commercial potential of strategic coal technologies, helping mitigate risk associated with marketplace adoption.

While only detailed Phase I applications are being solicited at this time, information relating to preliminary plans to carry out Phases II and III will be required to assess the potential viability of the overall project.

Only Phase I recipients will be afforded the opportunity to submit a Phase II application for consideration under the competitive down-selection process outlined in this NOFO.

At a minimum, at the end of Phase I (all TAs), it is anticipated that the recipients accomplish the following:

• Completed pre-FEED for the upgraded coal electric generation facility, with an Association for the Advancement of Cost Engineering (AACE) Class 4 cost estimate (pre-FEED guidelines provided in eXCHANGE listed under the “Documents” Section).

• Select an appropriate site for construction and/or hosting of the demonstration.

• Received host site commitment letter from the selected host site.

• Completed Environmental Information Volume (EIV) to assess any NEPA-related issues at the selected site. The purpose of the EIV is to initiate analysis of the selected host site from a NEPA perspective. Phase II recipients will complete the NEPA process so that demonstration and validation efforts can begin immediately for those projects selected for Phase III. In order to prepare for this, after Phase I recipients select the preferred host site, a completed EIV, that provides all initial environmental data and details about the proposed actions to take place at the site will be a required final Phase I deliverable.

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• Secured commitment letters from all team members necessary for Phase II, such as an Engineering Design contractor, a NEPA contractor, and any required technology partners or vendors.

• Updated the preliminary cost and schedule estimates for Phase II and Phase III.

• Secured any needed recipient cost share commitments for Phase II and formulated a realistic plan for securing any needed recipient cost share for Phase III.

• Completed preliminary business case analysis that quantifies the projected financial parameters

(e.g., operating costs, operating revenues, financing cash flows, EBITDA, tax credits/liabilities, ROI) over the project lifespan.

• Completed Project Management Plan (PMP) (Phase II and III), an updated Risk Management Plan, Risk Register (Phase II and III), and Safety Plan.

If the applicant has already conducted or is currently conducting activities meeting the above description of Phase I under a different award or at private expense, the status of such activities should be clearly described in the Technical Volume, and only complementary (but not redundant) additional activities should be proposed. Applicants who are conducting or have already conducted most of the required Phase I activities under a different award but still want to be in consideration for Phase II awards should propose a limited scope and budget for Phase I covering only those additional activities that are necessary to meet Phase II application requirements. Updates to existing work (such as improving the cost estimate and schedule for future phases) are allowable activities in Phase I as long as they are not identical to tasks that are already complete or will be completed as part of an existing award.

C. Expected Performance Goals Overarching performance goals for all three topic areas target achievement of the NOFO Program Objectives executed through a structured, well-informed stage-gate approach.

The key performance goal for Phase I awards is completion of sufficient front-end project development activities that support the technical and economic feasibility that awarded projects can achieve the Program goals and objectives of the relevant topic area.

The key performance goal for projects that emerge from the downselect process (i.e., projects that proceed to Phase II) is successful testing and validation of the technologies of interest.

Specific technical performance requirements are described in NOFO Section III.E (Topic Areas) and application requirements are articulated in NOFO Section IV.A.3 (Application Technical Volume Specific Requirements).

D. Topic Areas

Topic Area 1 - Development and Implementation of Advanced Wastewater Management Systems

Coal-fired power plants (CFPPs) are significant water users, requiring large volumes for cooling towers, quenching bottom ash, and flue-gas scrubbing. Consequently, they generate various wastewater streams that can contain heavy metals such as arsenic, lead, mercury, and selenium, as well as bromide, chlorides, and nitrates. Costs for treating these wastewater streams can represent a significant portion of CFPPs’ overall operating budget, impacting the competitiveness of coal-fired generation.

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Coal-fired power plants are confronted with the dual imperative of reducing wastewater discharge containing heavy metals and other pollutants, while simultaneously striving to extend their operational service life and reduce operational costs. Current wastewater management solutions often present formidable capital expenditures (CAPEX) and operating expenditures (OPEX), limited adaptability to varied influent conditions, and underdeveloped pathways for commercial byproduct recovery, thereby impeding their widespread adoption and the long-term economic sustainability of these power generation assets. Meeting these stringent requirements cost-effectively while maintaining operational viability and extending the service life of coal power plants is a significant challenge.

The objective of TA-1 is to validate transformational, cost-effective wastewater management systems that enhance water recovery from wastewater streams at CFPPs, reduce operational costs, and/or enhance commercial byproduct recovery. System attributes of interest include energy efficiency optimization and capital cost reduction with emphasis on prioritizing recovery of high-quality byproducts.

Wastewater streams of interest include, but are not limited to, flue gas desulfurization (FGD) wastewater, bottom ash (BA) transport water, and combustion residual leachate. Wastewater management systems anticipated to be proposed include, but are not limited to, chemical precipitation, membrane filtration, biological treatment, spray drying, thermal evaporation, encapsulation, and/or other emerging technologies with a minimum validated TRL 7.

The topic area will fund the development, engineering, implementation (i.e., construction, and operational validation/testing) of transformational wastewater management systems at existing coal plants. Funding is intended to support engineering, detailed design, installation and testing of innovative transformational wastewater management technologies integrated with existing plant infrastructure.

The effort will also include a CCUS system conceptual design that will reduce CO2 emissions and provide opportunities for EOR/EGR when using either coal or natural gas fuels.

Technology implementation should be completed on a minimum 50% slipstream of an actual wastewater stream at existing coal electric generation facility for at least six months of continuous operation. Awarded projects will be required to collect sufficiently detailed cost and performance data to support the scalability and economic viability of the technology of interest.

Topic Area 2 – Engineering and Implementation of Dual Firing Retrofits:

Dual-firing allows power plants to burn both coal and natural gas individually and interchangeably, providing significant operational flexibility. This approach is gaining traction due to rising coal-firing costs and a market shift towards natural gas, driven by lower prices. Dual-firing helps coal-fired utilities adapt to changing market and regulatory conditions, ensuring their viability and competitiveness.

Retrofitting offers numerous benefits. It provides operational flexibility, allowing plants to respond to fuel cost fluctuations and market demands, managing expenses more efficiently. A key advantage is leveraging existing infrastructure, as grid interconnections are already established, bypassing costly new developments. This enables utilities to continue utilizing significant capital investments in existing power plants.

The primary goal of a dual-fuel retrofit is to assess the economic and technical feasibility of integrating natural gas into existing coal-fired boilers. This involves developing a transformational systems that can automatically switch between fuels without compromising critical operational parameters. The retrofit aims to maintain the plant's Maximum Continuous Rating (MCR) for full power output and optimal heat rate on either fuel, ensure continuous compliance with emissions regulations, and protect component life.

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The effort will also include a CCUS system conceptual design that will reduce CO2 emissions and provide opportunities for EOR/EGR when using either coal or natural gas fuels. Ultimately, the retrofit must be economically sound, offering a favorable return on investment and improving generation economics and equipment reliability.

However, dual-firing retrofits present significant challenges due to the distinct characteristics of coal and natural gas regarding flame, heat absorption, emissions, and fouling. Accommodating these differences often requires major mechanical modifications to the boiler, including adjustments to heat transfer surfaces, burners and windboxes, and potential material upgrades.

A sophisticated control system is also essential for seamless fuel management. Therefore, a comprehensive assessment must consider equipment modifications, performance impacts, fuel supply logistics, and financial risks.

This topic area aims to enable coal plants to seamlessly switch between coal and natural gas, achieving full steam capacity and emissions compliance (e.g., NOx < 0.2 lb/mmBtu, CO < 100 ppm), while optimizing combustion efficiency and economic flexibility to extend plant lifespans. Modifications must meet all relevant ASME Boiler Code and NFPA 85 Boiler and Combustion Systems Hazards Code requirements.

Funding will support the engineering, implementation, and testing of dual-fuel firing retrofits for existing coal boilers. This includes developing burner/overfire air (OFA) systems, heat transfer surface modifications, potential emissions controls modifications, and automated burner management controls for safe and reliable fuel switching. Successful applications will demonstrate the ability to switch from 100% coal to 100% natural gas offline and under automatic control, achieving 100% MCR with full emissions compliance using either fuel.

Activities include engineering studies for infrastructure adaptation and prototype testing to optimize combustion and validate performance. Funding also supports training and system integration for automatic operation, reducing capital costs, and enhancing competitiveness against natural gas price volatility, and development of a CCUS conceptual design to reduce CO2 emissions and provide additional revenue opportunities via EOR/EGR. Concepts that include carbon utilization are preferred over approaches that solely implement carbon capture and storage.

Topic Area 3 – Development and Testing of Natural Gas Cofiring Systems:

Co-firing enables coal power plants to simultaneously burn coal and natural gas in their boilers, utilizing either single-fuel or dual-fuel burners. This method has become a popular retrofit for existing coal-fired facilities, allowing them to adapt to changing operational and environmental needs. Co-firing offers significant benefits for coal power plants, primarily reducing emissions of mercury, SO2, NOx, particulate matter, and CO2, proportional to natural gas heat input. This improvement stems from natural gas's lack of fuel-bound nitrogen, sulfur, and ash. Additionally, co-firing can lower operating costs by decreasing operation and maintenance expenses, and can significantly reduce auxiliary power consumption associated with coal-related equipment. It also enhances operational flexibility by improving low-load capability compared to exclusive coal firing.

Despite its advantages, co-firing presents notable challenges. The main difficulty lies in managing the distinct combustion characteristics of coal and natural gas, which differ in flame behavior, heat absorption, and emission profiles. Addressing this often requires major mechanical modifications to the boiler during retrofits, including adjustments to heat transfer surfaces, burners, windboxes, and boiler auxiliaries, along with potential material upgrades. Effective mixing of the two fuels is crucial;

Page 20 of 48 Version 3.0 inadequate mixing can lead to uneven heating, excessive ash deposition, and localized temperature imbalances, impacting combustion efficiency, increasing auxiliary power consumption, and raising furnace exit gas temperatures (FEGT). Moreover, a sophisticated control system capable of seamlessly managing varying fuel proportions and loads is essential for successful co-firing.

The objective of this program on coal/natural gas co-firing is to develop transformational boiler systems that automatically and smoothly controls any proportion of coal and natural gas co-firing. The goal is to leverage commercially ready technologies while exploring innovative approaches to reduce capital costs, improve equipment reliability, and enhance the overall efficiency of the retrofitted coal power plant.

This topic area aims to develop an optimal natural gas co-firing level and system design that maximizes gas co-firing capability without requiring major redesign of the boiler steam/superheat/reheat system.

Optimal co-firing rates should reduce SOx, NOx, Hg, and CO2 emissions by 20-50% while limiting retrofit costs to approximately $50/kW, maintaining boiler efficiency and reliability, and meeting regulatory and market demands. This system must maintain operational flexibility without compromising the plant's Maximum Continuous Rating (MCR), ensuring optimal heat rate, full compliance with emissions regulations, maintaining or enhancing component life, and favorable generation economics. Funding will support advancing natural gas co-firing system components, including burner modifications for 20-50% gas input, advanced control systems for fuel balance and sequencing, system integration of auxiliary equipment, and validation testing to optimize emissions and minimize efficiency losses, and a CCUS conceptual design to reduce CO2 emissions and provide additional revenue opportunities via EOR/EGR.

Concepts that include carbon utilization are preferred over approaches that solely implement carbon capture and storage.

Recipients must collect and report detailed cost and performance data to quantify CO2 abatement costs ($25-60/ton), parasitic load reductions that mitigate efficiency impact, and maintenance savings that ensure cost-effective compliance and sustainability.

E. Applications Specifically Not of Interest The following types of applications will be deemed non-responsive and will not be reviewed or considered (Please also refer to the Responsiveness Review section below):

• Applications that fall outside the technical parameters specified in Background and Context above and the Topic Areas section above.

• Applications for proposed technologies that are not based on sound scientific principles (e.g., violates the laws of thermodynamics).

• Applications proposing host sites other than steam electric generating units capable of being fired with coal on a…