{"id":754679,"date":"2023-05-04T06:05:59","date_gmt":"2023-05-04T10:05:59","guid":{"rendered":"https:\/\/www.marketnewsdesk.com\/index.php\/targa-resources-corp-reports-first-quarter-2023-financial-results\/"},"modified":"2023-05-04T06:05:59","modified_gmt":"2023-05-04T10:05:59","slug":"targa-resources-corp-reports-first-quarter-2023-financial-results","status":"publish","type":"post","link":"https:\/\/www.marketnewsdesk.com\/index.php\/targa-resources-corp-reports-first-quarter-2023-financial-results\/","title":{"rendered":"Targa Resources Corp. Reports First Quarter 2023 Financial Results"},"content":{"rendered":"
\n

HOUSTON, May 04, 2023 (GLOBE NEWSWIRE) — Targa Resources Corp. (NYSE: TRGP) (\u201cTRGP,\u201d the \u201cCompany\u201d or \u201cTarga\u201d) today reported first quarter 2023 results.<\/p>\n

First quarter 2023 net income attributable to Targa Resources Corp. was $497.0 million compared to $88.0 million for the first quarter of 2022.<\/p>\n

The Company reported adjusted earnings before interest, income taxes, depreciation and amortization, and other non-cash items (\u201cadjusted EBITDA\u201d) of $940.6 million for the first quarter of 2023 compared to $625.8 million for the first quarter of 2022. The Company reported distributable cash flow and adjusted free cash flow for the first quarter of 2023 of $729.4 million and $314.0 million, respectively.<\/p>\n

On April 13, 2023, the Company declared an increase to its quarterly cash dividend to $0.50 per common share, or $2.00 per common share on an annualized basis for the first quarter of 2023. Total cash dividends of approximately $113 million will be paid on May 15, 2023 on all outstanding shares of common stock to holders of record as of the close of business on April 28, 2023.<\/p>\n

Targa repurchased 724,140 shares of its common stock during the first quarter of 2023 at a weighted average per share price of $71.82 for a total net cost of $52.0 million. There was $91.8 million remaining under the Company\u2019s $500 million common share repurchase program as of March 31, 2023. On May 3, 2023, the Company\u2019s Board of Directors approved a new share repurchase program for the repurchase of up to $1.0 billion of the Company\u2019s outstanding common stock. The amount authorized under the new share repurchase program is in addition to the amount remaining under the existing share repurchase program.<\/p>\n

\n
\n First Quarter 2023 – Sequential Quarter over Quarter Commentary<\/u>
\n <\/strong>\n <\/p>\n

Targa reported first quarter 2023 adjusted EBITDA of $940.6 million, representing a 12 percent increase when compared to the fourth quarter of 2022. The sequential increase in adjusted EBITDA was primarily attributable to increased optimization margin realized in Targa\u2019s marketing and LPG export businesses, contribution from the recent acquisition of the remaining 25 percent interest in its Grand Prix NGL Pipeline (\u201cGrand Prix\u201d), and higher volumes across Targa\u2019s Gathering and Processing (\u201cG&P\u201d) and Logistics and Transportation (\u201cL&T\u201d) systems. In the G&P segment, sequential adjusted operating margin was approximately flat as margin attributable to record Permian natural gas inlet volumes and higher fees was offset by lower realized commodity prices. The increase in natural gas inlet volumes in the Permian was attributable to continued high levels of producer activity. In the L&T segment, higher marketing margin, coupled with higher sequential pipeline transportation, fractionation and LPG export volumes, drove the sequential increase in segment adjusted operating margin. Marketing margin was higher due to greater optimization opportunities. LPG export volumes were higher due to improved export market conditions. Higher NGL pipeline transportation and fractionation volumes were primarily due to higher supply volumes from Targa\u2019s Permian G&P systems. Lower G&A expenses were primarily attributable to lower compensation expenses, while higher operating expenses were primarily attributable to increased activity levels.<\/p>\n

\n
\n Capitalization and Liquidity<\/u>
\n <\/strong>\n <\/p>\n

The Company\u2019s total consolidated debt as of March 31, 2023 was $12,178.6 million, net of $67.7 million of debt issuance costs and $41.0 million of unamortized discount, with $9,534.4 million of outstanding senior notes, $1.5 billion outstanding under the Company\u2019s $1.5 billion term loan facility, $305.0 million outstanding under the Commercial Paper Program, $704.0 million outstanding under the Securitization Facility, and $243.9 million of finance lease liabilities.<\/p>\n

Total consolidated liquidity as of March 31, 2023 was approximately $2.6 billion, including $2.4 billion available under the TRGP Revolver and $211.8 million of cash.<\/p>\n

\n
\n Growth Projects Update<\/u>
\n <\/strong>\n <\/p>\n

In Permian Midland, construction continues on Targa\u2019s 275 million cubic feet per day (\u201cMMcf\/d\u201d) Greenwood plant. In Permian Delaware, construction continues on its 275 MMcf\/d Midway plant, 275 MMcf\/d Wildcat II plant and 230 MMcf\/d Roadrunner II plant. Additionally, Targa is ordering long-lead time items for another gas plant in the Permian Basin. In its L&T segment, construction continues on Targa\u2019s 120 thousand barrels per day (\u201cMBbl\/d\u201d) fractionation train (\u201cTrain 9\u201d) in Mont Belvieu, Texas, and its Daytona NGL Pipeline. Targa remains on-track to complete these expansions as previously disclosed.<\/p>\n

To handle continued supply growth anticipated from Targa\u2019s Permian G&P systems and third parties, Targa announced today its plans to construct a new 120 MBbl\/d fractionation train in Mont Belvieu, Texas (\u201cTrain 10\u201d). Train 10 is expected to begin operations in the first quarter of 2025.<\/p>\n

\n
\n 2023 Outlook<\/u>
\n <\/strong>\n <\/p>\n

While commodity prices\u00a0are lower than the assumptions underlying Targa\u2019s previously disclosed full year financial estimates for 2023, there is no change to Targa\u2019s expectation to generate full year adjusted EBITDA between $3.5 billion and $3.7 billion for 2023. With today\u2019s announcement related to moving ahead with the construction of its Train 10 fractionator in Mont Belvieu and incremental spending associated with long-lead time items for another gas plant in the Permian Basin, Targa now estimates total net growth capital expenditures for 2023 to be between $2.0 billion and $2.2 billion. Targa’s estimate for 2023 net maintenance capital expenditures remains unchanged at approximately $175 million. Please see the section of this release entitled \u201cNon-GAAP Financial Measures\u201d for a discussion of forward-looking estimated adjusted EBITDA and a reconciliation of such measure to its most directly comparable GAAP financial measure.<\/p>\n

An earnings supplement presentation and an updated investor presentation are available under Events and Presentations in the Investors section of the Company\u2019s website at www.targaresources.com\/investors\/events<\/u><\/a>.<\/p>\n

\n
\n Conference Call <\/u>
\n <\/strong>\n <\/p>\n

The Company will host a conference call for the investment community at 11:00 a.m. Eastern time (10:00 a.m. Central time) on May 4, 2023 to discuss its first quarter results. The conference call can be accessed via webcast under Events and Presentations in the Investors section of the Company\u2019s website at www.targaresources.com\/investors\/events<\/u><\/a>, or by going directly to https:\/\/edge.media-server.com\/mmc\/p\/4bdw3s4z<\/u><\/a>. A webcast replay will be available at the link above approximately two hours after the conclusion of the event.<\/p>\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n
\n
\n Targa Resources Corp. \u2013 Consolidated Financial Results of Operations<\/u>
\n <\/strong>
\n \n <\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\n Three Months Ended March\u00a031,<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\n 2023<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2023 vs. 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\n (In millions)<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
Revenues:<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Sales of commodities<\/td>\n$<\/td>\n4,025.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n4,566.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n(541.2<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(12<\/td>\n%)<\/td>\n<\/tr>\n
Fees from midstream services<\/td>\n\u00a0<\/td>\n495.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n392.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n102.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n26<\/td>\n%<\/td>\n<\/tr>\n
Total revenues<\/td>\n\u00a0<\/td>\n4,520.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n4,959.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(438.6<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(9<\/td>\n%)<\/td>\n<\/tr>\n
Product purchases and fuel<\/td>\n\u00a0<\/td>\n3,019.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n4,204.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(1,185.1<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(28<\/td>\n%)<\/td>\n<\/tr>\n
Operating expenses<\/td>\n\u00a0<\/td>\n258.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n183.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n74.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n41<\/td>\n%<\/td>\n<\/tr>\n
Depreciation and amortization expense<\/td>\n\u00a0<\/td>\n324.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n209.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n115.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n55<\/td>\n%<\/td>\n<\/tr>\n
General and administrative expense<\/td>\n\u00a0<\/td>\n82.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n67.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n15.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n23<\/td>\n%<\/td>\n<\/tr>\n
Other operating (income) expense<\/td>\n\u00a0<\/td>\n(0.6<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(0.5<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(0.1<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n20<\/td>\n%<\/td>\n<\/tr>\n
Income (loss) from operations<\/td>\n\u00a0<\/td>\n836.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n295.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n540.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n183<\/td>\n%<\/td>\n<\/tr>\n
Interest expense, net<\/td>\n\u00a0<\/td>\n(168.0<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(93.6<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(74.4<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n79<\/td>\n%<\/td>\n<\/tr>\n
Equity earnings (loss)<\/td>\n\u00a0<\/td>\n(0.2<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n5.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(5.8<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(104<\/td>\n%)<\/td>\n<\/tr>\n
Gain (loss) from financing activities<\/td>\n\u00a0<\/td>\n\u2014<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(15.8<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n15.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n100<\/td>\n%<\/td>\n<\/tr>\n
Other, net<\/td>\n\u00a0<\/td>\n(3.0<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(0.5<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(2.5<\/td>\n)<\/td>\n\u00a0<\/td>\nNM<\/td>\n\u00a0<\/td>\n<\/tr>\n
Income tax (expense) benefit<\/td>\n\u00a0<\/td>\n(110.3<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(22.9<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(87.4<\/td>\n)<\/td>\n\u00a0<\/td>\nNM<\/td>\n\u00a0<\/td>\n<\/tr>\n
Net income (loss)<\/td>\n\u00a0<\/td>\n555.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n168.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n386.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n229<\/td>\n%<\/td>\n<\/tr>\n
Less: Net income (loss) attributable to noncontrolling interests<\/td>\n\u00a0<\/td>\n58.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n80.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(22.4<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(28<\/td>\n%)<\/td>\n<\/tr>\n
Net income (loss) attributable to Targa Resources Corp.<\/td>\n\u00a0<\/td>\n497.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n88.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n409.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\nNM<\/td>\n\u00a0<\/td>\n<\/tr>\n
Premium on repurchase of noncontrolling interests, net of tax<\/td>\n\u00a0<\/td>\n490.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n53.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n437.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\nNM<\/td>\n\u00a0<\/td>\n<\/tr>\n
Dividends on Series A Preferred Stock<\/td>\n\u00a0<\/td>\n\u2014<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n21.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(21.8<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(100<\/td>\n%)<\/td>\n<\/tr>\n
Net income (loss) attributable to common shareholders<\/td>\n$<\/td>\n6.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n13.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n(6.8<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(52<\/td>\n%)<\/td>\n<\/tr>\n
\n Financial data:<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Adjusted EBITDA (1)<\/td>\n$<\/td>\n940.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n625.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n314.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n50<\/td>\n%<\/td>\n<\/tr>\n
Distributable cash flow (1)<\/td>\n\u00a0<\/td>\n729.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n494.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n234.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n47<\/td>\n%<\/td>\n<\/tr>\n
Adjusted free cash flow (1)<\/td>\n\u00a0<\/td>\n314.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n373.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(59.2<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(16<\/td>\n%)<\/td>\n<\/tr>\n<\/table>\n

\n (1)\u00a0 \u00a0 \u00a0 \u00a0Adjusted EBITDA, distributable cash flow and adjusted free cash flow are non-GAAP financial measures and are discussed under \u201cNon-GAAP Financial Measures.\u201d <\/sub>
\n
\n NM\u00a0 \u00a0 Due to a low denominator, the noted percentage change is disproportionately high and as a result, considered not meaningful.<\/sub>\n <\/p>\n

\n Three Months Ended March 31, 2023 Compared to Three Months Ended March 31, 2022 <\/em>\n <\/p>\n

The decrease in commodity sales reflects lower NGL, natural gas and condensate prices ($1,769.2 million), partially offset by higher NGL, natural gas and condensate volumes ($682.1 million) and the favorable impact of hedges ($546.0 million).<\/p>\n

The increase in fees from midstream services is primarily due to higher gas gathering and processing fees including the impact of the acquisition of certain assets in the Delaware Basin.<\/p>\n

The decrease in product purchases and fuel reflects lower NGL, natural gas and condensate prices, partially offset by higher NGL, natural gas and condensate volumes.<\/p>\n

The increase in operating expenses is primarily due to increased activity and system expansions, the acquisition of certain assets in the Delaware Basin and South Texas, and higher costs attributable to inflation.<\/p>\n

See \u201c\u2014Review of Segment Performance\u201d for additional information on a segment basis.<\/p>\n

The increase in depreciation and amortization expense is primarily due to the acquisition of certain assets in the Delaware Basin and South Texas, the shortening of depreciable lives of certain assets that have been, or will be, idled and the impact of system expansions on our asset base.<\/p>\n

The increase in general and administrative expense is primarily due to higher compensation and benefits, insurance costs and professional fees.<\/p>\n

The increase in interest expense, net is due to higher net borrowings primarily for the acquisition of certain assets in the Delaware Basin and the Grand Prix Transaction, partially offset by higher capitalized interest resulting from higher growth capital investments.<\/p>\n

During 2022, the Partnership redeemed the 5.375% Senior Notes due 2027. In addition, the Company terminated the previous TRGP senior secured revolving credit facility and the Partnership\u2019s senior secured revolving credit facility. These transactions resulted in a net loss from financing activities.<\/p>\n

The increase in income tax expense is primarily due to an increase in pre-tax book income, partially offset by a larger release of the valuation allowance in 2023 compared to 2022.<\/p>\n

The decrease in net income (loss) attributable to noncontrolling interests is primarily due to the Grand Prix Transaction and lower income allocation to noncontrolling interest holders in the Carnero Joint Venture.<\/p>\n

The premium on repurchase of noncontrolling interests, net of tax is due to the Grand Prix Transaction in 2023 and the purchase of all of Stonepeak Infrastructure Partners’ interests in the Company’s development company joint ventures in 2022.<\/p>\n

The decrease in dividends on Series A Preferred Stock (\u201cSeries A Preferred\u201d) is due to the full redemption of all of the Company’s issued and outstanding shares of Series A Preferred in May 2022.<\/p>\n

\n
\n Review of Segment Performance<\/u>
\n <\/strong>\n <\/p>\n

The following discussion of segment performance includes inter-segment activities. The Company views segment operating margin and adjusted operating margin as important performance measures of the core profitability of its operations. These measures are key components of internal financial reporting and are reviewed for consistency and trend analysis. For a discussion of adjusted operating margin, see \u201cNon-GAAP Financial Measures \u2015 Adjusted Operating Margin.\u201d Segment operating financial results and operating statistics include the effects of intersegment transactions. These intersegment transactions have been eliminated from the consolidated presentation.<\/p>\n

The Company operates in two primary segments: (i) Gathering and Processing; and (ii) Logistics and Transportation.<\/p>\n

\n
\n Gathering and Processing Segment<\/em>
\n <\/strong>\n <\/p>\n

The Gathering and Processing segment includes assets used in the gathering and\/or purchase and sale of natural gas produced from oil and gas wells, removing impurities and processing this raw natural gas into merchantable natural gas by extracting NGLs; and assets used for the gathering and terminaling and\/or purchase and sale of crude oil. The Gathering and Processing segment’s assets are located in the Permian Basin of West Texas and Southeast New Mexico (including the Midland, Central and Delaware Basins); the Eagle Ford Shale in South Texas; the Barnett Shale in North Texas; the Anadarko, Ardmore, and Arkoma Basins in Oklahoma (including the SCOOP and STACK) and South Central Kansas; the Williston Basin in North Dakota (including the Bakken and Three Forks plays); and the onshore and near offshore regions of the Louisiana Gulf Coast and the Gulf of Mexico.<\/p>\n

The following table provides summary data regarding results of operations of this segment for the periods indicated:<\/p>\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n\n
\u00a0<\/td>\n\n Three Months Ended March\u00a031,<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\n 2023<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2023 vs. 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\n (In millions, except operating statistics and price amounts)<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
Operating margin<\/td>\n$<\/td>\n\u00a0<\/td>\n538.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n397.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n140.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n35<\/td>\n%<\/td>\n<\/tr>\n
Operating expenses<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n181.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n116.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n64.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n56<\/td>\n%<\/td>\n<\/tr>\n
Adjusted operating margin<\/td>\n$<\/td>\n\u00a0<\/td>\n719.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n514.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n205.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n40<\/td>\n%<\/td>\n<\/tr>\n
\n Operating statistics (1):<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Plant natural gas inlet, MMcf\/d (2) (3)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Permian Midland (4)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n2,348.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n2,075.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n273.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n13<\/td>\n%<\/td>\n<\/tr>\n
Permian Delaware (5)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n2,495.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n977.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1,518.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n155<\/td>\n%<\/td>\n<\/tr>\n
Total Permian<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n4,843.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n3,052.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1,791.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n59<\/td>\n%<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
SouthTX (6)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n355.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n162.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n193.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n120<\/td>\n%<\/td>\n<\/tr>\n
North Texas<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n195.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n175.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n20.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n12<\/td>\n%<\/td>\n<\/tr>\n
SouthOK (6)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n383.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n407.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(23.4<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(6<\/td>\n%)<\/td>\n<\/tr>\n
WestOK<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n204.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n202.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1<\/td>\n%<\/td>\n<\/tr>\n
Total Central<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1,139.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n947.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n192.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n20<\/td>\n%<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Badlands (6) (7)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n131.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n125.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n6.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n5<\/td>\n%<\/td>\n<\/tr>\n
Total Field<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n6,114.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n4,124.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1,990.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n48<\/td>\n%<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Coastal<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n509.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n602.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(92.9<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(15<\/td>\n%)<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Total<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n6,624.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n4,726.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1,897.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n40<\/td>\n%<\/td>\n<\/tr>\n
NGL production, MBbl\/d (3)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Permian Midland (4)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n335.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n300.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n34.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n11<\/td>\n%<\/td>\n<\/tr>\n
Permian Delaware (5)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n342.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n129.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n212.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n164<\/td>\n%<\/td>\n<\/tr>\n
Total Permian<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n677.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n430.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n247.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n57<\/td>\n%<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
SouthTX (6)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n38.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n20.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n18.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n89<\/td>\n%<\/td>\n<\/tr>\n
North Texas<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n23.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n19.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n3.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n20<\/td>\n%<\/td>\n<\/tr>\n
SouthOK (6)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n38.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n50.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(11.7<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(23<\/td>\n%)<\/td>\n<\/tr>\n
WestOK<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n13.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n14.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(1.8<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(12<\/td>\n%)<\/td>\n<\/tr>\n
Total Central<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n113.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n104.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n8.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n8<\/td>\n%<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Badlands (6)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n15.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n14.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n0.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n5<\/td>\n%<\/td>\n<\/tr>\n
Total Field<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n806.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n550.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n256.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n47<\/td>\n%<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Coastal<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n36.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n37.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(0.9<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(2<\/td>\n%)<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Total<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n842.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n587.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n255.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n43<\/td>\n%<\/td>\n<\/tr>\n
Crude oil, Badlands, MBbl\/d<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n110.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n122.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(12.1<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(10<\/td>\n%)<\/td>\n<\/tr>\n
Crude oil, Permian, MBbl\/d<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n25.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n30.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(5.1<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(17<\/td>\n%)<\/td>\n<\/tr>\n
Natural gas sales, BBtu\/d (3)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n2,572.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n2,126.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n446.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n21<\/td>\n%<\/td>\n<\/tr>\n
NGL sales, MBbl\/d (3)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n459.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n424.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n34.3<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n8<\/td>\n%<\/td>\n<\/tr>\n
Condensate sales, MBbl\/d<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n19.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n14.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n5.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n38<\/td>\n%<\/td>\n<\/tr>\n
\n Average realized prices – inclusive of hedges (8):<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
Natural gas, $\/MMBtu<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n2.63<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n4.09<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(1.46<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(36<\/td>\n%)<\/td>\n<\/tr>\n
NGL, $\/gal<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n0.52<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n0.79<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(0.27<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(34<\/td>\n%)<\/td>\n<\/tr>\n
Condensate, $\/Bbl<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n66.34<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n75.72<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(9.38<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(12<\/td>\n%)<\/td>\n<\/tr>\n<\/table>\n

\n (1)\u00a0 \u00a0 \u00a0 \u00a0Segment operating statistics include the effect of intersegment amounts, which have been eliminated from the consolidated presentation. For all volume statistics presented, the numerator is the total volume sold during the period and the denominator is the number of calendar days during the period.
(2)\u00a0 \u00a0 \u00a0 \u00a0Plant natural gas inlet represents the Company\u2019s 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.<\/sub>
\n
\n (3)\u00a0 \u00a0 \u00a0 \u00a0Plant natural gas inlet volumes and gross NGL production volumes include producer take-in-kind volumes, while natural gas sales and NGL sales exclude producer take-in-kind volumes.<\/sub>
\n
\n (4)\u00a0 \u00a0 \u00a0 \u00a0Permian Midland includes operations in WestTX, of which the Company owns a 72.8% undivided interest, and other plants that are owned 100% by the Company. Operating results for the WestTX undivided interest assets are presented on a pro-rata net basis in the Company\u2019s reported financials<\/sub>
\n
\n (5)\u00a0 \u00a0 \u00a0 \u00a0Includes operations from the acquisition of certain assets in the Delaware Basin for the period effective August 1, 2022.<\/sub>
\n
\n (6)\u00a0 \u00a0 \u00a0 \u00a0Operations include facilities that are not wholly owned by the Company. SouthTX operating statistics include the impact of the acquisition of certain assets in South Texas for the period effective April 21, 2022.<\/sub>
\n
\n (7)\u00a0 \u00a0 \u00a0 \u00a0Badlands natural gas inlet represents the total wellhead volume and includes the Targa volumes processed at the Little Missouri 4 plant.<\/sub>
\n
\n (8)\u00a0 \u00a0 \u00a0 \u00a0Average realized prices include the effect of realized commodity hedge gain\/loss attributable to the Company\u2019s equity volumes. The price is calculated using total commodity sales plus the hedge gain\/loss as the numerator and total sales volume as the denominator.<\/sub>\n <\/p>\n

The following table presents the realized commodity hedge gain (loss) attributable to the Company\u2019s equity volumes that are included in the adjusted operating margin of the Gathering and Processing segment:<\/p>\n\n\n\n\n\n\n\n\n
\u00a0<\/td>\n\u00a0<\/td>\n\n Three Months Ended March 31, 2023<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n Three Months Ended March 31, 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\n (In millions, except volumetric data and price amounts)<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\n Volume <\/strong>
\n
\n Settled<\/strong>\n <\/td>\n		\u00a0<\/td>\n\u00a0<\/td>\n\n Price <\/strong>
\n
\n Spread (1)<\/strong>\n <\/td>\n		\u00a0<\/td>\n\u00a0<\/td>\n\n Gain <\/strong>
\n
\n (Loss)<\/strong>\n <\/td>\n		\u00a0<\/td>\n\u00a0<\/td>\n\n Volume <\/strong>
\n
\n Settled<\/strong>\n <\/td>\n		\u00a0<\/td>\n\u00a0<\/td>\n\n Price <\/strong>
\n
\n Spread (1)<\/strong>\n <\/td>\n		\u00a0<\/td>\n\u00a0<\/td>\n\n Gain <\/strong>
\n
\n (Loss)<\/strong>\n <\/td>\n		\u00a0<\/td>\n<\/tr>\n
Natural gas (BBtu)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n19.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n1.35<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n26.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n17.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n(1.78<\/td>\n)<\/td>\n\u00a0<\/td>\n$<\/td>\n(31.2<\/td>\n)<\/td>\n<\/tr>\n
NGL (MMgal)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n184.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n0.05<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n9.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n170.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(0.46<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(78.0<\/td>\n)<\/td>\n<\/tr>\n
Crude oil (MBbl)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n0.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(4.67<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(2.8<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n0.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(39.40<\/td>\n)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n(19.7<\/td>\n)<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n33.2<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n(128.9<\/td>\n)<\/td>\n<\/tr>\n<\/table>\n

\n (1)\u00a0 \u00a0 \u00a0 \u00a0The price spread is the differential between the contracted derivative instrument pricing and the price of the corresponding settled commodity transaction.<\/sub>\n <\/p>\n

\n Three Months Ended March 31, 2023 Compared to Three Months Ended March 31, 2022 <\/em>\n <\/p>\n

The increase in adjusted operating margin was due to higher natural gas inlet volumes and higher fees resulting in increased margin predominantly in the Permian, partially offset by lower commodity prices. The increase in natural gas inlet volumes in the Permian was attributable to the acquisition of certain assets in the Delaware Basin during the third quarter of 2022, the addition of the Legacy and Red Hills VI plants during the third quarter of 2022 and continued strong producer activity. Natural gas inlet volumes in the Central region increased primarily due to the acquisition of certain assets in South Texas during the second quarter of 2022. The decrease in volumes in the Coastal region was attributable to lower production.<\/p>\n

The increase in operating expenses was predominantly due to the acquisition of certain assets in South Texas and the Delaware Basin in the second and third quarters of 2022. Additionally, higher volumes in the Permian, the addition of the Legacy and Red Hills VI plants in the third quarter of 2022 and inflation impacts resulted in increased costs.<\/p>\n

\n
\n Logistics and Transportation Segment<\/em>
\n <\/strong>\n <\/p>\n

The Logistics and Transportation segment includes the activities and assets necessary to convert mixed NGLs into NGL products and also includes other assets and value-added services such as transporting, storing, fractionating, terminaling, and marketing of NGLs and NGL products, including services to LPG exporters and certain natural gas supply and marketing activities in support of the Company\u2019s other businesses. The Logistics and Transportation segment also includes Grand Prix NGL Pipeline, which connects the Company\u2019s gathering and processing positions in the Permian Basin, Southern Oklahoma and North Texas with the Company\u2019s Downstream facilities in Mont Belvieu, Texas. The associated assets are generally connected to and supplied in part by the Company\u2019s Gathering and Processing segment and, except for the pipelines and smaller terminals, are located predominantly in Mont Belvieu and Galena Park, Texas, and in Lake Charles, Louisiana.<\/p>\n

The following table provides summary data regarding results of operations of this segment for the periods indicated:<\/p>\n\n\n\n\n\n\n\n\n\n\n\n\n
\u00a0<\/td>\n\n Three Months Ended March\u00a031,<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\n 2023<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2023 vs. 2022<\/strong>\n <\/td>\n<\/tr>\n
\u00a0<\/td>\n\n (In millions, except operating statistics)<\/strong>\n <\/td>\n<\/tr>\n
Operating margin<\/td>\n$<\/td>\n\u00a0<\/td>\n529.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n352.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n177.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n50<\/td>\n%<\/td>\n<\/tr>\n
Operating expenses<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n76.5<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n66.9<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n9.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n14<\/td>\n%<\/td>\n<\/tr>\n
Adjusted operating margin<\/td>\n$<\/td>\n\u00a0<\/td>\n605.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n419.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n\u00a0<\/td>\n186.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n45<\/td>\n%<\/td>\n<\/tr>\n
\n Operating statistics MBbl\/d (1):<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
NGL pipeline transportation volumes (2)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n536.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n459.7<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n77.1<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n17<\/td>\n%<\/td>\n<\/tr>\n
Fractionation volumes<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n758.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n702.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n56.0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n8<\/td>\n%<\/td>\n<\/tr>\n
Export volumes (3)<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n373.4<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n340.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n32.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n10<\/td>\n%<\/td>\n<\/tr>\n
NGL sales<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n1,007.6<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n872.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n134.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n15<\/td>\n%<\/td>\n<\/tr>\n<\/table>\n

\n (1)\u00a0 \u00a0 \u00a0 \u00a0Segment operating statistics include intersegment amounts, which have been eliminated from the consolidated presentation. For all volume statistics presented, the numerator is the total volume sold during the period and the denominator is the number of calendar days during the period.
(2)\u00a0 \u00a0 \u00a0 \u00a0Represents the total quantity of mixed NGLs that earn a transportation margin.<\/sub>
\n
\n (3)\u00a0 \u00a0 \u00a0 \u00a0Export volumes represent the quantity of NGL products delivered to third-party customers at the Company\u2019s Galena Park Marine Terminal that are destined for international markets.<\/sub>\n <\/p>\n

\n Three Months Ended March 31, 2023 Compared to Three Months Ended March 31, 2022 <\/em>\n <\/p>\n

The increase in adjusted operating margin was due to higher marketing margin, higher pipeline transportation and fractionation margin, and higher LPG export margin. Marketing margin increased due to greater optimization opportunities. Pipeline transportation and fractionation volumes benefited primarily from higher supply volumes from the Company’s Permian Gathering and Processing systems. LPG export margin increased due to higher volumes and fees.<\/p>\n

The increase in operating expenses was due to higher taxes and higher compensation and benefits.<\/p>\n

\n
\n Other<\/em>
\n <\/strong>\n <\/p>\n\n\n\n\n\n\n\n
\u00a0<\/td>\n\u00a0<\/td>\n\n Three Months Ended March\u00a031,<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\n 2023<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\n 2023 vs. 2022<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\n (In millions)<\/strong>\n <\/td>\n\u00a0<\/td>\n<\/tr>\n
Operating margin<\/td>\n\u00a0<\/td>\n$<\/td>\n175.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n(178.3<\/td>\n)<\/td>\n\u00a0<\/td>\n$<\/td>\n354.1<\/td>\n\u00a0<\/td>\n<\/tr>\n
Adjusted operating margin<\/td>\n\u00a0<\/td>\n$<\/td>\n175.8<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n$<\/td>\n(178.3<\/td>\n)<\/td>\n\u00a0<\/td>\n$<\/td>\n354.1<\/td>\n\u00a0<\/td>\n<\/tr>\n
\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n\u00a0<\/td>\n<\/tr>\n<\/table>\n

Other contains the results of commodity derivative activity mark-to-market gains\/losses related to derivative contracts that were not designated as cash flow hedges. The Company has entered into derivative instruments to hedge the commodity price associated with a portion of the Company\u2019s future commodity purchases and sales and natural gas transportation basis risk within the Company\u2019s Logistics and Transportation segment.<\/p>\n

\n
\n About Targa Resources Corp.<\/u>
\n <\/strong>\n <\/p>\n

Targa Resources Corp. is a leading provider of midstream services and is one of the largest independent midstream infrastructure companies in North America. The Company owns, operates, acquires and develops a diversified portfolio of complementary domestic midstream infrastructure assets and its operations are critical to the efficient, safe and reliable delivery of energy across the United States and increasingly to the world. The Company\u2019s assets connect natural gas and NGLs to domestic and international markets with growing demand for cleaner fuels and feedstocks. The Company is primarily engaged in the business of: gathering, compressing, treating, processing, transporting, and purchasing and selling natural gas; transporting, storing, fractionating, treating, and purchasing and selling NGLs and NGL products, including services to LPG exporters; and gathering, storing, terminaling, and purchasing and selling crude oil.<\/p>\n

Targa is a FORTUNE 500 company and is included in the S&P 500.<\/p>\n

For more information, please visit the Company\u2019s website at www.targaresources.com<\/u><\/a>.<\/p>\n

\n
\n Non-GAAP Financial Measures <\/u>
\n <\/strong>\n <\/p>\n

This press release includes the Company\u2019s non-GAAP financial measures: adjusted EBITDA, distributable cash flow, adjusted free cash flow and adjusted operating margin (segment). The following tables provide reconciliations of these non-GAAP financial measures to their most directly comparable GAAP measures.<\/p>\n

The Company utilizes non-GAAP measures to analyze the Company\u2019s performance. Adjusted EBITDA, distributable cash flow, adjusted free cash flow and adjusted operating margin (segment) are non-GAAP measures. The GAAP measures most directly comparable to these non-GAAP measures are income (loss) from operations, Net income (loss) attributable to Targa Resources Corp. and segment operating margin. These non-GAAP measures should not be considered as an alternative to GAAP measures and have important limitations as analytical tools. Investors should not consider these measures in isolation or as a substitute for analysis of the Company\u2019s results as reported under GAAP. Additionally, because the Company\u2019s non-GAAP measures exclude some, but not all, items that affect income and segment operating margin, and are defined differently by different companies within the Company\u2019s industry, the Company\u2019s definitions may not be comparable with similarly titled measures of other companies, thereby diminishing their utility. Management compensates for the limitations of the Company\u2019s non-GAAP measures as analytical tools by reviewing the comparable GAAP measures, understanding the differences between the measures and incorporating these insights into the Company\u2019s decision-making processes.<\/p>\n

\n Adjusted Operating Margin <\/strong>\n <\/p>\n

The Company defines adjusted operating margin for the Company\u2019s segments as revenues less product purchases and fuel. It is impacted by volumes and commodity prices as well as by the Company\u2019s contract mix and commodity hedging program.<\/p>\n

Gathering and Processing adjusted operating margin consists primarily of:<\/p>\n