Targa Resources Corp

Previous wording

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in our Annual Report on Form 10-K for the year ended December 31, 2023 (“Annual Report”), as well as the unaudited consolidated financial statements and notes hereto included in this Quarterly Report on Form 10-Q for the quarter ended September 30, 2024 (“Quarterly Report”).

Current wording

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with Management’s Discussion and Analysis of Financial Condition and Results of Operations in our annual report on Form 10-K for the year ended December 31, 2024 (“Annual Report”), as well as the unaudited consolidated financial statements and notes hereto included in this quarterly report on Form 10-Q for the quarter ended March 31, 2025 (“Quarterly Report”).

Previous wording

Targa Resources Corp. (NYSE: TRGP) is a publicly traded Delaware corporation formed in October 2005. Targa is a leading provider of midstream services and is one of the largest independent midstream infrastructure companies in North America. We own, operate, acquire, and develop a diversified portfolio of complementary domestic midstream infrastructure assets.

Current wording

Targa Resources Corp. (NYSE: TRGP) is a publicly traded Delaware corporation formed in October 2005. Targa is a leading provider of midstream services and is one of the largest independent infrastructure companies in North America. We own, operate, acquire, and develop a diversified portfolio of complementary domestic infrastructure assets.

Previous wording

In May 2024, we announced the construction of a new 275 MMcf/d cryogenic natural gas processing plant in Permian Midland (the “Pembrook II plant”). The Pembrook II plant is expected to begin operations in the fourth quarter of 2025.

Current wording

In May 2024, we announced the construction of a new 275 MMcf/d cryogenic natural gas processing plant in Permian Midland (the “Pembrook II plant”). The Pembrook II plant is expected to begin operations in the third quarter of 2025.

Previous wording

In August 2023, we announced the construction of a new 275 MMcf/d cryogenic natural gas processing plant in Permian Delaware (the “Bull Moose plant”). The Bull Moose plant is expected to begin operations in the first quarter of 2025.

Current wording

In August 2023, we announced the construction of a new 275 MMcf/d cryogenic natural gas processing plant in Permian Delaware (the “Bull Moose plant”). The Bull Moose plant commenced operations in the first quarter of 2025.

Previous wording

In January 2023, we reached an agreement with our partners in Gulf Coast Fractionators (“GCF”) to reactivate GCF’s 135 MBbl/d fractionation facility. GCF is expected to begin operations in the fourth quarter of 2024.

Current wording

In January 2023, we reached an agreement with our partners in Gulf Coast Fractionators (“GCF”) to reactivate GCF’s 135 MBbl/d fractionation facility. GCF commenced operations in the first quarter of 2025.

Previous wording

On July 31, 2024, we entered into an agreement with the WPC Joint Venture (“WPC”) to move forward with the Blackcomb Pipeline (“Blackcomb”). Blackcomb is designed to transport up to 2.5 Bcf/d of natural gas through approximately 365 miles of 42-inch pipeline from the Permian Basin in West Texas to the Agua Dulce area in South Texas, and is expected to be in service in the second half of 2026, pending the receipt of customary regulatory and other approvals. Blackcomb is a joint venture owned 70.0% by WPC, 17.5% by Targa, and 12.5% by MPLX LP. WPC is a joint venture owned 50.6% by WhiteWater, 30.4% by MPLX LP, and 19.0% by Enbridge Inc. During the third quarter of 2024, we made an initial capital contribution of $12.8 million to Blackcomb.

Current wording

On July 31, 2024, we entered into a joint venture (“Blackcomb Joint Venture”) to construct and operate the Blackcomb pipeline. The Blackcomb Joint Venture is owned 70.0% by WPC, 17.5% by Targa, and 12.5% by MPLX LP. WPC is a joint venture owned 50.6% by WhiteWater, 30.4% by MPLX LP, and 19.0% by Enbridge Inc. The Blackcomb pipeline is designed to transport up to 2.5 Bcf/d of natural gas through approximately 365 miles of 42-inch pipeline from the Permian Basin in West Texas to the Agua Dulce area in South Texas, and is expected to be in service in the second half of 2026, pending the receipt of customary regulatory and other approvals.

Previous wording

In April 2024, we declared an increase to our quarterly common dividend to $0.75 per common share, or $3.00 per common share annualized effective for the first quarter of 2024.

Current wording

In April 2025, we declared an increase to our quarterly common dividend to $1.00 per common share, or $4.00 per common share annualized, effective for the first quarter of 2025.

Previous wording

In May 2023, our Board of Directors approved a $1.0 billion common share repurchase program (the “2023 Share Repurchase Program”). In July 2024, our Board of Directors approved a new $1.0 billion common share repurchase program (the “2024 Share Repurchase Program” and, together with the 2023 Share Repurchase Program, the “Share Repurchase Programs”). The amount authorized under the 2024 Share Repurchase Program was in addition to the amount remaining under the 2023 Share Repurchase Program. We are not obligated to repurchase any specific dollar amount or number of shares under these Share Repurchase Programs and may discontinue these programs at any time.

Current wording

In May 2023, our Board of Directors approved a $1.0 billion common share repurchase program (the “2023 Share Repurchase Program”). In July 2024, our Board of Directors approved a new $1.0 billion common share repurchase program (the “2024 Share Repurchase Program and, together with the 2023 Share Repurchase Program, the “Share Repurchase Programs”). The amount authorized under the 2024 Share Repurchase Program was in addition to the amount remaining under the 2023 Share Repurchase Program. During the first quarter of 2025, we exhausted the 2023 Share Repurchase Program. We are not obligated to repurchase any specific dollar amount or number of shares under the 2024 Share Repurchase Program and may discontinue the program at any time.

Previous wording

For the three and nine months ended September 30, 2024, we repurchased 1,150,107 shares and 5,322,367 shares of our common stock at a weighted average per share price of $146.02 and $121.50 for a total net cost of $167.9 million and $646.7 million, respectively. As of September 30, 2024, there was $1.1 billion remaining under the Share Repurchase Programs.

Current wording

For the three months ended March 31, 2025, we repurchased 651,163 shares of our common stock at a weighted average per share price of $191.86 for a total net cost of $124.9 million. As of March 31, 2025, there was $890.5 million remaining under the 2024 Share Repurchase Program.

Previous wording

In August 2024, we completed an underwritten public offering of $1.0 billion aggregate principal amount of our 5.500% Senior Notes due 2035 (the “5.500% Notes”), resulting in net proceeds of approximately $990.1 million. We used the net proceeds from the issuance to repay borrowings under the Commercial Paper Program, a portion of which were incurred to repay the remaining balance under the Term Loan Facility, and for general corporate purposes.

Current wording

In February 2025, we completed an underwritten public offering of (i) $1.0 billion aggregate principal amount of our 5.550% Senior Unsecured Notes due 2035 (the “5.550% Notes due 2035”) and (ii) $1.0 billion aggregate principal amount of our 6.125% Senior Unsecured Notes due 2055 (the “6.125% Notes due 2055”), resulting in net proceeds of approximately $2.0 billion. The 5.550% Notes due 2035 and 6.125% Notes due 2055 are fully and unconditionally guaranteed, jointly and severally, on a senior unsecured basis by our subsidiaries that guarantee the TRGP Revolver, so long as such subsidiary guarantors satisfy certain conditions. We used the net proceeds from the debt issuance to fund the Badlands Transaction and the remaining net proceeds for general corporate purposes, including to repay borrowings under our unsecured commercial paper note program (the “Commercial Paper Program”).

Previous wording

Federal statutes of limitations for returns filed in 2020 (for calendar year 2019) have expired, except for the 2019 returns under examination that have a statute extension to December 2025. The statute of limitations expired on substantially all 2019 state income tax returns that were filed prior to October 15, 2020. For Texas, the statute of limitations has expired for 2020 returns (for calendar year 2019). However, tax authorities could review and adjust carryover attributes (e.g., net operating losses) generated in a closed tax year if utilized in an open tax year.

Current wording

Federal statutes of limitations for returns filed in 2021 (for calendar year 2020) have expired. The 2019 returns under examination have a statute extension to December 2025. The statute of limitations expired on substantially all 2020 state income tax returns that were filed prior to October 15, 2021. For Texas, the statute of limitations has expired for 2020 returns (for calendar year 2019). However, tax authorities could review and adjust carryover attributes (e.g., net operating losses) generated in a closed tax year if utilized in an open tax year.

Previous wording

The U.S. Department of the Treasury and the IRS have issued guidance on the application of the corporate alternative minimum tax (the “CAMT”), including proposed regulations issued in September 2024, which may be relied upon until final regulations are issued. Based on our interpretation of the Inflation Reduction Act of 2022 (the “IRA”), the CAMT and related guidance, and several operational, economic, accounting and regulatory assumptions, we do not anticipate qualifying as an “applicable corporation” in the near term, but we are likely to become an applicable corporation in a subsequent tax year. If we become an applicable corporation and our CAMT liability is greater than our regular U.S. federal income tax liability for any particular tax year, the CAMT liability would effectively accelerate our future U.S. federal income tax obligations, reducing our cash available for distribution in that year, but provide an offsetting credit against our regular U.S. federal income tax liability for the future. As a result, our current expectation is that the impact of the CAMT is limited to timing differences in future tax years. Given the complexities of the IRA and CAMT, we will continue to monitor and evaluate the potential future impact to our financial statements.

Current wording

The U.S. Department of the Treasury and the IRS have issued guidance on the application of the corporate alternative minimum tax (the “CAMT”), including proposed regulations issued in September 2024, which may be relied upon until final regulations are released. Based on our interpretation of the Inflation Reduction Act of 2022 (the “IRA”), the CAMT and related guidance, and several operational, economic, accounting and regulatory assumptions, we are currently not an “applicable corporation”, but we are likely to become one in a subsequent year, potentially as early as 2026. If we become an applicable corporation and our CAMT liability is greater than our regular U.S. federal income tax liability for any particular tax year, the CAMT liability would effectively accelerate our future U.S. federal income tax obligations, reducing our cash available for distribution in that year, but provide an offsetting credit against our regular U.S. federal income tax liability for the future. As a result, our current expectation is that the impact of the CAMT is limited to timing differences in future tax years. Given the complexities of the IRA and the CAMT and the possibility that the CAMT will be reduced or eliminated by the new Presidential administration, we will continue to monitor and evaluate the potential future impact to our financial statements.

Previous wording

Our profitability is impacted by our ability to add new sources of natural gas supply and crude oil supply to offset the natural decline of existing volumes from oil and natural gas wells that are connected to our gathering and processing systems. This is achieved by connecting new wells and adding new volumes in existing areas of production, as well as by capturing crude oil and natural gas supplies currently gathered by third parties. Similarly, our profitability is impacted by our ability to add new sources of mixed NGL supply, connected by third-party transportation and Grand Prix, to our Downstream Business fractionation facilities and at times to our export facilities. We fractionate NGLs generated by our gathering and processing plants, as well as by contracting for mixed NGL supply from third-party facilities.

Current wording

Our profitability is impacted by our ability to add new sources of crude oil supply and natural gas supply to offset the natural decline of existing volumes from oil and natural gas wells that are connected to our gathering and processing systems. This is achieved by connecting new wells and adding new volumes in existing areas of production, as well as by capturing crude oil and natural gas supplies currently gathered by third parties. Similarly, our profitability is impacted by our ability to add new sources of mixed NGL supply, connected by third-party transportation and Grand Prix, to our Downstream Business fractionation facilities and at times to our export facilities. We fractionate NGLs generated by our gathering and processing plants, as well as by contracting for mixed NGL supply from third-party facilities.

Previous wording

We define adjusted cash flow from operations as adjusted EBITDA less cash interest expense on debt obligations and cash tax (expense) benefit. We define adjusted free cash flow as adjusted cash flow from operations less maintenance capital expenditures (net of any reimbursements of project costs) and growth capital expenditures, net of contributions from noncontrolling interest and contributions to investments in unconsolidated affiliates. Adjusted cash flow from operations and adjusted free cash flow are performance measures used by us and by external users of our financial statements, such as investors, commercial banks and research analysts, to assess our ability to generate cash earnings (after servicing our debt and funding capital expenditures) to be used for corporate purposes, such as payment of dividends, retirement of debt or redemption of other financing arrangements.

Current wording

We define adjusted cash flow from operations as adjusted EBITDA less cash interest expense on debt obligations and cash tax (expense) benefit. We define adjusted free cash flow as adjusted cash flow from operations less maintenance capital expenditures (net of any reimbursements of project costs) and growth capital expenditures, net of contributions from noncontrolling interests and including contributions to investments in unconsolidated affiliates. Adjusted cash flow from operations and adjusted free cash flow are performance measures used by us and by external users of our financial statements, such as investors, commercial banks and research analysts, to assess our ability to generate cash earnings (after servicing our debt and funding capital expenditures) to be used for corporate purposes, such as payment of dividends, retirement of debt or redemption of other financing arrangements.

Previous wording

The following tables reconcile the non-GAAP financial measures used by management to the most directly comparable GAAP measures for the periods indicated:

Current wording

The following table reconciles the non-GAAP financial measures used by management to the most directly comparable GAAP measures for the periods indicated:

Previous wording

Excludes amortization of interest expense. The nine months ended September 30, 2024 includes $55.8 million of interest expense associated with the Splitter Agreement ruling.

Current wording

Excludes amortization of interest expense. The three months ended March 31, 2024 includes $54.9 million of interest expense on a 2024 legal ruling associated with an agreement, dated December 27, 2015, for crude oil and condensate between Targa Channelview LLC, then a subsidiary of the Company, and Noble Americas Corp (the “Splitter Agreement”).

Previous wording

The following table and discussion is a summary of our consolidated results of operations for the periods indicated:

Current wording

The following table and discussion summarize our consolidated results of operations for the periods indicated:

Previous wording

Commodity sales are relatively flat reflecting lower natural gas prices ($1,051.9 million) and the unfavorable impact of hedges ($559.2 million), offset by higher NGL, natural gas and condensate volumes ($1,369.1 million), and higher NGL and condensate prices ($53.9 million).

Current wording

Commodity sales are relatively flat reflecting lower NGL, natural gas and condensate volumes ($217.9 million), the unfavorable impact of hedges ($256.1 million) and lower condensate prices ($15.2 million), offset by higher natural gas and NGL prices ($431.2 million).

Previous wording

The increase in fees from midstream services is primarily due to higher gas gathering and processing fees, higher transportation fees and higher export volumes, partially offset by lower fractionation fees.

Current wording

The increase in fees from midstream services is primarily due to higher gas gathering and processing fees, and higher export volumes, partially offset by lower transportation and fractionation fees.

Previous wording

Product purchases and fuel are relatively flat reflecting higher NGL and natural gas volumes, offset by lower natural gas prices.

Current wording

Product purchases and fuel are relatively flat reflecting higher natural gas and NGL prices, offset by lower NGL and natural gas volumes.

Previous wording

The increase in operating expenses is primarily due to higher labor and maintenance costs as a result of increased activity and system expansions, partially offset by lower taxes.

Current wording

The increase in operating expenses is primarily due to higher labor, taxes and maintenance costs, partially offset by lower rental costs.

Previous wording

The increase in depreciation and amortization expense is primarily due to the impact of system expansions on our asset base that have been placed in service since September 30, 2023.

Current wording

The increase in depreciation and amortization expense is primarily due to the impact of system expansions on our asset base.

Previous wording

The increase in interest expense, net, is due to recognition of cumulative interest on a 2024 legal ruling associated with the Splitter Agreement and higher borrowings, partially offset by an increase in capitalized interest. See Note 12 – Contingencies for additional information related to the legal ruling.

Current wording

The decrease in interest expense, net is due to recognition of cumulative interest on a legal ruling associated with the Splitter Agreement in 2024, partially offset by higher borrowings in 2025.

Previous wording

The increase in income tax expense is primarily due to an increase in pre-tax book income.

Current wording

The decrease in income tax expense is primarily due to a decrease in pre-tax book income.

Previous wording

The premium on repurchase of noncontrolling interests, net of tax is due to the acquisition of Blackstone Energy Partners’ 25% interest in the Grand Prix Joint Venture in 2023 (the “Grand Prix Transaction”).

Current wording

The premium on repurchase of noncontrolling interests, net of tax is due to the Badlands Transaction in 2025.

Previous wording

Plant natural gas inlet represents our undivided interest in the volume of natural gas passing through the meter located at the inlet of a natural gas processing plant, other than Badlands.

Current wording

Plant natural gas inlet represents our undivided interest in the volume of natural gas passing through the meter located at the inlet of a natural gas processing plant, other than Badlands during 2024.

Previous wording

The increase in adjusted operating margin was primarily due to higher natural gas inlet volumes and higher fees in the Permian, partially offset by lower natural gas prices. The increase in natural gas inlet volumes in the Permian was attributable to the addition of the Legacy II plant during the first quarter of 2023, the Midway plant during the second quarter of 2023, the Greenwood I and Wildcat II plants during the fourth quarter of 2023, the Roadrunner II plant during the second quarter of 2024, and continued strong producer activity.

Current wording

The increase in adjusted operating margin was predominantly due to higher natural gas inlet volumes in the Permian. The increase in natural gas inlet volumes in the Permian was attributable to the addition of the Roadrunner II plant during the second quarter of 2024, the Greenwood II plant during the fourth quarter of 2024, the Bull Moose plant during the first quarter of 2025, and continued strong producer activity despite severe winter weather events which impacted volumes during the first quarter of 2025.

Previous wording

The increase in adjusted operating margin was due to higher pipeline transportation and fractionation margin, higher marketing margin, and higher LPG export margin. Pipeline transportation and fractionation volumes benefited from higher supply volumes primarily from our Permian Gathering and Processing systems and the addition of Train 9 during the second quarter of 2024. Marketing margin increased due to greater optimization opportunities. LPG export margin increased due to higher volumes as the company benefited from the completion of its export expansion during the third quarter of 2023 and the Houston Ship Channel allowing night-time vessel transits, partially offset by maintenance and required inspections.

Current wording

The increase in adjusted operating margin was due to higher pipeline transportation and fractionation margin and higher marketing margin. Pipeline transportation and fractionation volumes benefited from higher supply volumes primarily from our Permian Gathering and Processing systems, the addition of Train 9 during the second quarter of 2024, the in-service of the Daytona NGL Pipeline during the third quarter of 2024, and the addition of Train 10 during the fourth quarter of 2024. Marketing margin increased due to greater optimization opportunities.

Previous wording

The increase in total growth capital expenditures was primarily due to system expansions in the Permian region in response to forecasted production growth and higher activity levels, and expansions in our Downstream business. The increase in total maintenance capital expenditures was primarily due to our growing infrastructure footprint.

Current wording

The increase in operating expenses was predominantly due to system expansions.

Previous wording

On a consolidated basis, our main sources of liquidity and capital resources are internally generated cash flows from operations, borrowings under the $2.75 billion TRGP senior revolving credit facility (the “TRGP Revolver”), the unsecured commercial paper note program (the “Commercial Paper Program”), the Securitization Facility, and access to debt and equity capital markets. We supplement these sources of liquidity with joint venture arrangements and proceeds from asset sales. Our exposure to adverse credit conditions includes our credit facilities, cash investments, hedging abilities, customer performance risks and counterparty performance risks.

Current wording

As of March 31, 2025, inclusive of our consolidated joint venture accounts, we had $151.4 million of Cash and cash equivalents on our Consolidated Balance Sheets. On a consolidated basis, our main sources of liquidity and capital resources are internally generated cash flows from operations, borrowings under the TRGP Revolver, the Commercial Paper Program, the $600.0 million accounts receivable securitization facility (the “Securitization Facility”), and access to debt and equity capital markets. We supplement these sources of liquidity with joint venture arrangements and proceeds from asset sales. Our exposure to adverse credit conditions includes our credit facilities, cash investments, hedging abilities, customer performance risks and counterparty performance risks.

Previous wording

On a consolidated basis, our ability to finance our operations, including funding capital expenditures and acquisitions, meeting our indebtedness obligations, refinancing or repaying our indebtedness, meeting our collateral requirements and to pay dividends declared by our Board of Directors will depend on our ability to generate cash in the future. Our ability to generate cash is subject to a number of factors, some of which are beyond our control. These include commodity prices and ongoing efforts to manage operating costs and maintenance capital expenditures, as well as general economic, financial, competitive, legislative, regulatory and other factors. For additional discussion on recent factors impacting our liquidity and capital resources, please see “Recent Developments.”

Current wording

We believe our sources of liquidity and capital resources are sufficient to meet our anticipated cash requirements for at least the next twelve months to satisfy our obligations, including our day-to-day operations, growth capital expenditures, dividend payments, maintenance capital expenditures, debt service and other anticipated obligations. Our ability to generate cash is subject to a number of factors, some of which are beyond our control. These include commodity prices and ongoing efforts to manage operating costs and maintenance capital expenditures, as well as general economic, financial, competitive, legislative, regulatory and other factors. For additional discussion on recent factors impacting our liquidity and capital resources, see “Recent Developments.”

Previous wording

Other potential capital resources associated with our existing arrangements include our right to request an additional $500.0 million in commitment increases under the TRGP Revolver, subject to the terms therein. The TRGP Revolver matures on February 17, 2027.

Current wording

Other potential capital resources associated with our existing arrangements include our right to request an additional $500.0 million in commitment increases under the TRGP Revolver, subject to the terms therein. The TRGP Revolver matures on February 18, 2030. The maturity date is extendable, subject to the lenders’ consent, by one year up to two times.

Previous wording

A portion of our capital resources are allocated to letters of credit to satisfy certain counterparty credit requirements. As of September 30, 2024, we had $15.5 million in letters of credit outstanding under the TRGP Revolver. The letters of credit also reflect certain counterparties’ views of our financial condition and ability to satisfy our performance obligations, as well as commodity prices and other factors.

Current wording

A portion of our capital resources are allocated to letters of credit to satisfy certain counterparty credit requirements. As of March 31, 2025, we had $9.4 million in letters of credit outstanding under the TRGP Revolver. The letters of credit also reflect certain counterparties’ views of our financial condition and ability to satisfy our performance obligations, as well as commodity prices and other factors.

Previous wording

Working capital as of September 30, 2024 decreased $32.8 million compared to December 31, 2023. The decrease was primarily due to higher accounts payable related to capital spending on growth projects, lower net assets for hedging activities and higher borrowings on the Securitization Facility, partially offset by lower interest payable.

Current wording

Working capital as of March 31, 2025 decreased $245.6 million compared to December 31, 2024. The decrease was primarily due to a higher outstanding balance on the Securitization Facility, lower receivables resulting from lower NGL and natural gas volumes and higher net liabilities for hedging activities, partially offset by lower payables, including interest and accounts payable balances related to capital spending on growth projects.

Previous wording

In August 2024, we completed an underwritten public offering of the 5.500% Notes, resulting in net proceeds of approximately $990.1 million. We used the net proceeds from the issuance to repay borrowings under the Commercial Paper Program, a portion of which were incurred to repay the remaining balance under the Term Loan Facility, and for general corporate purposes.

Current wording

In February 2025, we completed an underwritten public offering of the 5.550% Notes due 2035 and the 6.125% Notes 2055, resulting in net proceeds of approximately $2.0 billion. We used the net proceeds from the debt issuance to fund the Badlands Transaction and for general corporate purposes, including to repay borrowings under the Commercial Paper Program.

Previous wording

The primary drivers of cash flows from operating activities are: (i) the collection of cash from customers from the sale of NGLs and natural gas, as well as fees for processing, gathering, export, fractionation, terminaling, storage and transportation; (ii) the payment of amounts related to the purchase of NGLs, natural gas and crude oil; and (iii) the payment of other expenses, primarily field operating costs, general and administrative expense and interest expense. In addition, we use derivative instruments to manage our exposure to commodity price risk. Changes in the prices of the commodities we hedge impact our derivative settlements as well as our margin deposit requirements on unsettled futures contracts.

Current wording

The primary drivers of cash flows from operating activities are: (i) the collection of cash from customers from the sale of NGLs and natural gas, as well as fees for processing, gathering, export, fractionation, terminaling, storage and transportation; (ii) the payment of amounts related to the purchase of NGLs and natural gas; and (iii) the payment of other expenses, primarily field operating costs, general and administrative expense and interest expense. In addition, we use derivative instruments to manage our exposure to commodity price risk. Changes in the prices of the commodities we hedge impact our derivative settlements as well as our margin deposit requirements on unsettled futures contracts.

Previous wording

The increase in net cash provided by operating activities was primarily due to higher collections from customers resulting from increased revenues during 2024 compared to 2023, partially offset by an increase in payments for product purchases and fuel, purchases of inventory, lower settlements on our hedging transactions, and a nonrecurring one-time payment associated with the Splitter Agreement ruling. See further details in “Part II — Item 1. Legal Proceedings.”

Current wording

The increase in net cash provided by operating activities was primarily due to higher collections from customers resulting from increased revenues in 2025 compared to 2024, partially offset by an increase in payments for product purchases and fuel, higher operating expenses, higher interest payments, and higher outlays for hedging transactions.

Previous wording

The increase in net cash used in investing activities was due to higher outlays for property, plant and equipment in 2024 primarily related to construction activities in the Permian region and Mont Belvieu, Texas.

Current wording

The increase in net cash used in investing activities was due to higher outlays for major growth capital projects in 2025 primarily related to construction activities in the Permian region and Mont Belvieu, Texas.

Previous wording

The decrease in net cash used in financing activities was due to lower repurchases of noncontrolling interests primarily due to the Grand Prix Transaction in 2023, partially offset by higher repurchases of common stock and higher dividends paid in 2024.

Current wording

The decrease in net cash used in financing activities was due to higher proceeds from debt financings in 2025 and lower distributions to noncontrolling interests subsequent to the CBF Acquisition in the fourth quarter of 2024 and the Badlands Transaction in the first quarter of 2025, partially offset by higher repurchases of noncontrolling interests due to the Badlands Transaction, higher dividends paid and higher repurchases of common stock in 2025. The increase in proceeds from debt financings was due to higher proceeds from our senior unsecured notes and borrowings under the Securitization Facility, partially offset by higher repayments of the Commercial Paper Program.

Previous wording

Our subsidiaries that guarantee our obligations under the TRGP Revolver (the “Obligated Group”) also fully and unconditionally guarantee, jointly and severally, the payment of TRGP’s senior notes, subject to certain limited exceptions.

Current wording

Our subsidiaries that guarantee our obligations under the TRGP Revolver (the “Obligated Group”) also fully and unconditionally guarantee, jointly and severally, the payment of TRGP’s senior unsecured notes, subject to certain limited exceptions.