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Guidance history, every release

Chord Energy (CHRD) · 8 releases, Nov 6, 2024 to Aug 5, 2026 · rows are metrics, columns are releases

Raised · a change from the previous releaseSame · restated unchanged— · not stated in that releaseEvery value links to its sentence in the filing

Metric	Nov 6, 2024 FY24 Q3	Feb 25, 2025 FY24 Q4	May 6, 2025 FY25 Q1	Aug 6, 2025 FY25 Q2	Nov 4, 2025 FY25 Q3	Feb 25, 2026 FY25 Q4	May 5, 2026 FY26 Q1	Aug 5, 2026 FY26 Q2
For FY2026
Adjusted EBITDA	—	—	—	—	—	—	—	New“approximately $3.0B”
Adjusted EBITDA	—	—	—	—	—	New“approximately $2.3B”	Raised“approximately $3.1B”	—
Cash Tax (% of Adjusted EBITDA)	—	—	—	—	—	—	—	New“3% - 9%”
Cash Tax (% of Adjusted EBITDA)	—	—	—	—	—	—	—	New“4% - 12%”
Cash Tax (% of Adjusted EBITDA)	—	—	—	—	—	New“1% – 5%”	Raised“4% - 9%”	Narrowed“5% - 8%”
Cash Tax (% of Adjusted EBITDA)	—	—	—	New“3% – 10%”	Lowered“0% – 3%”	—	Raised“2% - 8%”	—
Cash Tax (% of Adjusted EBITDA)	—	—	—	—	—	New“0% – 3%”	—	—
1Q26 volumes at midpoint	—	—	—	—	—	New“154 MBopd”	—	—
2Q26 CapEx (midpoint)	—	—	—	—	—	—	New“$425MM”	—
2Q26 midpoint oil volume	—	—	—	—	—	—	New“164.0 MBopd”	—
3-mile laterals of TILs	—	—	—	—	—	New“~40%”	—	—
4-mile laterals share of spuds	—	—	—	—	—	—	New“60%”	—
4-mile laterals share of TILs	—	—	—	—	—	—	New“approximately 40%”	—
4-mile laterals share of TILs and spuds	—	—	—	—	—	—	New“approximately 40% of TILs and 60% of spuds”	—
Adjusted Free Cash Flow	—	—	—	—	—	—	—	New“$1.3B”
Adjusted Free Cash Flow	—	—	—	—	—	New“$700MM”	Raised“$1.4B”	—
Average working interest (TILs)	—	—	—	—	—	—	—	New“~75%”
Average working interest of planned TILs	—	—	—	—	—	—	New“~75%”	—
Average working interest of TILs	—	—	—	—	—	New“~75%”	—	—
CapEx	—	—	—	—	—	—	New“$1.4B”	—
CapEx	—	—	—	—	—	—	New“$425MM”	—
CapEx ($MM)	—	—	—	—	—	—	—	New“$360 - $390”
CapEx ($MM)	—	—	—	—	—	—	—	New“$242 - $292”
CapEx ($MM)	—	—	—	—	—	New“$1,350 – $1,450”	Narrowed“$1,355 - $1,445”	Narrowed“$1,360 - $1,440”
CapEx ($MM)	—	—	—	—	—	—	New“$410 - $440”	—
CapEx ($MM)	—	—	—	—	—	New“$325 – $355”	—	—
CapEx at midpoint of	—	—	—	—	—	New“$1.4B”	—	—
CapEx midpoint	—	—	—	—	—	—	—	New“$1.4B”
CapEx midpoint	—	—	—	—	—	—	—	New“$375MM”
Cash G&A ($MM)	—	—	—	—	—	—	—	New“$25 - $27”
Cash G&A ($MM)	—	—	—	—	—	—	—	New“$25 - $27”
Cash G&A ($MM)	—	—	—	—	—	New“$90 – $100”	Raised“$98 - $103”	Reiterated“$98 - $103”
Cash G&A ($MM)	—	—	—	New“$20 – $25”	Reiterated“$20 – $25”	—	Raised“$24 - $26”	—
Cash G&A ($MM)	—	—	—	—	—	New“$23 – $28”	—	—
Cash GPT ($/Boe)	—	—	—	—	—	—	—	New“$2.75 - $3.15”
Cash GPT ($/Boe)	—	—	—	—	—	—	—	New“$2.80 - $3.20”
Cash GPT ($/Boe)	—	—	—	—	—	New“$2.65 – $3.15”	Narrowed“$2.70 - $3.10”	Narrowed“$2.80 - $3.00”
Cash GPT ($/Boe)	—	—	—	New“$2.65 – $3.15”	Narrowed“$2.70 – $3.00”	—	Widened“$2.70 - $3.20”	—
Cash GPT ($/Boe)	—	—	—	—	—	New“$2.75 – $3.25”	—	—
Cash Interest ($MM)	—	—	—	—	—	—	—	New“$25 - $27”
Cash Interest ($MM)	—	—	—	—	—	—	—	New“$25 - $27”
Cash Interest ($MM)	—	—	—	—	—	New“$100 – $110”	Narrowed“$100 - $108”	Narrowed“$102 - $106”
Cash Interest ($MM)	—	—	—	New“$17 – $19”	Raised“$25 – $27”	—	Reiterated“$25 - $27”	—
Cash Interest ($MM)	—	—	—	—	—	New“$25 – $27”	—	—
Cash Taxes	—	—	—	—	New“1.5% of Adjusted EBITDA”	—	—	—
E&P & Other CapEx ($MM)	—	—	—	New“$315 – $345”	Reiterated“$315 – $345”	—	—	—
FY26 CapEx (midpoint, unchanged from February 2026)	—	—	—	—	—	—	New“$1.4B”	—
FY26 oil volumes (midpoint)	—	—	—	—	—	—	New“161 MBopd”	—
Gross operated TILs	—	—	—	—	—	New“135 – 165”	—	—
Gross operated TILs	—	—	—	New“30 – 40”	—	—	—	—
Gross operated TILs	—	—	—	New“30 – 40 gross operated TILs planned for 3Q25 (~70% working interest)”	—	—	—	—
Gross operated TILs (~80% working interest)	—	—	—	—	New“23 – 33”	—	—	—
Incremental CapEx (to support maintaining XTO volumes in 2026)	—	—	—	—	New“$15MM”	—	—	—
LOE	—	—	—	—	—	—	New“$9.95/BOE”	—
LOE	—	—	—	—	New“$9.70/Boe”	—	—	—
LOE ($/Boe)	—	—	—	—	—	—	—	New“$10.00 - $11.00”
LOE ($/Boe)	—	—	—	—	—	—	—	New“$10.00 - $11.00”
LOE ($/Boe)	—	—	—	—	—	New“$9.30 – $10.30”	Raised“$9.55 - $10.35”	Raised“$10.05 - $10.55”
LOE ($/Boe)	—	—	—	New“$9.15 – $10.15”	Raised“$9.20 – $10.20”	—	Raised“$9.70 - $10.70”	—
LOE ($/Boe)	—	—	—	—	—	New“$9.40 – $10.40”	—	—
LOE midpoint	—	—	—	—	—	—	—	New“$10.30/BOE”
Midpoint FY26 LOE	—	—	—	—	—	—	New“$9.95/BOE”	—
Midstream projects	—	—	—	—	—	New“~$30MM”	—	—
Midstream projects capital	—	—	—	—	—	New“~$30MM”	—	—
Natural Gas Realization (% of Henry Hub)	—	—	—	—	—	—	—	New“20% - 30%”
Natural Gas Realization (% of Henry Hub)	—	—	—	—	—	—	—	New“35% - 45%”
Natural Gas Realization (% of Henry Hub)	—	—	—	—	—	New“35% – 45%”	Narrowed“36% - 44%”	Narrowed“38% - 44%”
Natural Gas Realization (% of Henry Hub)	—	—	—	New“20% – 30%”	Raised“30% – 40%”	—	Lowered“25% - 35%”	—
Natural Gas Realization (% of Henry Hub)	—	—	—	—	—	New“50% – 60%”	—	—
Natural Gas Volumes (MMcfpd)	—	—	—	—	—	—	—	New“397.0 - 405.0”
Natural Gas Volumes (MMcfpd)	—	—	—	—	—	—	—	New“410.0 - 418.0”
Natural Gas Volumes (MMcfpd)	—	—	—	—	—	New“403.0 – 413.0”	Lowered“401.0 - 407.0”	Raised“406.6 - 410.6”
Natural Gas Volumes (MMcfpd)	—	—	—	New“430.0 – 442.0”	Lowered“421.0 – 433.0”	—	Lowered“400.0 - 408.0”	—
Natural Gas Volumes (MMcfpd)	—	—	—	—	—	New“401.0 – 409.0”	—	—
NGL Realization (% of WTI)	—	—	—	—	—	—	—	New“4% - 10%”
NGL Realization (% of WTI)	—	—	—	—	—	—	—	New“4% - 14%”
NGL Realization (% of WTI)	—	—	—	—	—	—	New“4% - 12%”	Narrowed“7% - 11%”
NGL Realization (% of WTI)	—	—	—	New“10% – 20%”	Lowered“5% – 15%”	—	Lowered“4% - 10%”	—
NGL Realization (% of WTI)	—	—	—	—	—	New“5% – 15%”	—	—
NGL Volumes (MBblpd)	—	—	—	—	—	—	—	New“50.0 - 52.0”
NGL Volumes (MBblpd)	—	—	—	—	—	—	—	New“49.0 - 51.0”
NGL Volumes (MBblpd)	—	—	—	—	—	New“49.5 – 50.5”	Reiterated“49.5 - 50.5”	Raised“50.2 - 51.4”
NGL Volumes (MBblpd)	—	—	—	New“50.5 – 54.5”	Lowered“49.5 – 53.5”	—	Narrowed“50.5 - 51.5”	—
NGL Volumes (MBblpd)	—	—	—	—	—	New“48.0 – 49.0”	—	—
Oil Discount to WTI ($/Bbl)	—	—	—	—	—	New“$(1.60) – $(2.60)”	—	—
Oil Discount to WTI ($/Bbl)	—	—	—	—	—	New“$(1.50) – $(2.50)”	—	—
Oil Discount to WTI ($/Bbl)	—	—	—	New“$(2.40) – $(0.40)”	Lowered“$(2.80) – $(0.80)”	—	—	—
Oil Premium/(Discount) to WTI ($/Bbl)	—	—	—	—	—	—	—	New“$(0.70) - $0.30”
Oil Premium/(Discount) to WTI ($/Bbl)	—	—	—	—	—	—	—	New“$(1.50) - $0.50”
Oil Premium/(Discount) to WTI ($/Bbl)	—	—	—	—	—	—	New“$(0.50) - $0.50”	Widened“$(0.80) - $(0.00)”
Oil Premium/(Discount) to WTI ($/Bbl)	—	—	—	—	—	—	New“$0.50 - $1.50”	—
Oil volume	—	—	—	—	—	—	New“164.0 MBopd”	—
Oil volume midpoint	—	—	—	—	—	—	—	New“161 MBopd”
Oil volume midpoint	—	—	—	—	—	—	—	New“163.0 MBopd”
Oil volumes	—	—	—	—	—	—	New“161 MBopd”	—
Oil volumes (excluding XTO Acquisition)	—	—	—	—	New“147.0 MBopd”	—	—	—
Oil Volumes (MBopd)	—	—	—	—	—	—	—	New“161.5 - 164.5”
Oil Volumes (MBopd)	—	—	—	—	—	—	—	New“156.0 - 159.0”
Oil Volumes (MBopd)	—	—	—	—	—	New“157.0 – 161.0”	Raised“160.0 - 162.0”	Narrowed“160.2 - 161.8”
Oil Volumes (MBopd)	—	—	—	New“153.5 – 157.5”	Lowered“149.0 – 153.0”	—	Raised“162.5 - 165.5”	—
Oil Volumes (MBopd)	—	—	—	—	—	New“152.5 – 155.5”	—	—
Oil volumes at midpoint of	—	—	—	—	—	New“159 MBopd”	—	—
Oil volumes contribution from XTO Acquisition	—	—	—	—	New“approximately 4.0 MBopd”	—	—	—
Oil Volumes Outlook	—	—	—	—	—	New“157 – 161 MBopd”	—	—
Portion of CapEx related to operated and non-operated drilling and completion activity	—	—	—	—	—	New“~90%”	—	—
Portion of FY26 CapEx incurred	—	—	—	—	—	New“~80%”	—	—
Production Taxes (% of Oil, NGL and Natural Gas Sales)	—	—	—	—	—	—	—	New“8.0% - 8.4%”
Production Taxes (% of Oil, NGL and Natural Gas Sales)	—	—	—	—	—	—	—	New“8.0% - 8.4%”
Production Taxes (% of Oil, NGL and Natural Gas Sales)	—	—	—	—	—	New“7.7% – 8.1%”	Narrowed“7.8% - 8.1%”	Raised“8.0% - 8.2%”
Production Taxes (% of Oil, NGL and Natural Gas Sales)	—	—	—	New“8.3% – 8.8%”	Reiterated“8.3% – 8.8%”	—	Lowered“7.9% - 8.3%”	—
Production Taxes (% of Oil, NGL and Natural Gas Sales)	—	—	—	—	—	New“7.5% – 7.9%”	—	—
Return of Capital (% of Adjusted Free Cash Flow)	—	—	—	—	—	—	—	New“75% of free cash flow”
Shareholder returns (% of free cash flow)	—	—	—	—	—	—	—	New“75%”
TIL gross operated wells	—	—	—	—	—	New“135 – 165”	—	Narrowed“140 – 160”
TIL gross operated wells plan	—	—	—	—	—	—	New“135 – 165”	—
TIL mix: 3-mile laterals	—	—	—	—	—	—	New“~40% 3-mile laterals”	—
TIL mix: 4-mile laterals	—	—	—	—	—	—	New“~40% 4-mile laterals”	—
Total oil volumes	—	—	—	—	New“151.0 MBopd”	—	—	—
Total oil volumes at midpoint (including XTO)	—	—	—	—	New“151.0 MBopd”	—	—	—
Total Volumes (MBoepd)	—	—	—	—	—	—	—	New“277.7 - 284.0”
Total Volumes (MBoepd)	—	—	—	—	—	—	—	New“273.3 - 279.7”
Total Volumes (MBoepd)	—	—	—	—	—	New“273.7 – 280.3”	Narrowed“276.4 - 280.3”	Raised“278.2 - 281.8”
Total Volumes (MBoepd)	—	—	—	New“275.7 – 285.7”	Lowered“268.7 – 278.7”	—	Raised“279.7 - 285.0”	—
Total Volumes (MBoepd)	—	—	—	—	—	New“267.3 – 272.7”	—	—
Volumes	—	—	—	—	—	New“154 MBopd”	—	—
For FY2025
Adjusted EBITDA	—	New“approximately $2.5B”	Lowered“approximately $2.2B”	Raised“approximately $2.4B”	Reiterated“approximately $2.4B”	—	—	—
Cash Tax (% of Adjusted EBITDA)	—	New“3% – 10%”	Narrowed“4% – 9%”	Lowered“3.5% – 6.5%”	Lowered“3% – 4%”	—	—	—
Cash Tax (% of Adjusted EBITDA)	—	—	New“2% – 9%”	—	—	—	—	—
Cash Tax (% of Adjusted EBITDA) (2)	—	New“1% – 7%”	—	—	—	—	—	—
Cash Tax (% of Adjusted EBITDA) (2)	—	New“3% – 10%”	—	—	—	—	—	—
Cash Tax (% of Adjusted EBITDA) (3)	New“0% – 5%”	—	—	—	—	—	—	—
% 3-mile laterals of TIL wells	—	New“approximately 40%”	—	—	—	—	—	—
% of E&P and other CapEx invested in drilling and completions	—	New“Approximately 80%”	—	—	—	—	—	—
1Q25 oil volumes (current expectation)	—	New“149.5 – 152.5 MBopd”	—	—	—	—	—	—
1Q25 volumes	—	New“149.5 – 152.5 MBopd”	—	—	—	—	—	—
3-mile laterals	—	—	New“~40% 3-mile laterals in 2025”	—	—	—	—	—
4-mile lateral TILs	—	—	—	New“seven 4-mile laterals in FY25”	—	—	—	—
4-mile laterals TIL'd	—	—	—	—	New“seven 4-mile laterals”	—	—	—
4Q24 base dividend	—	New“$1.30 per share”	—	—	—	—	—	—
Adjusted FCF	—	—	—	New“approximately $850MM”	Lowered“approximately $840MM”	—	—	—
Adjusted FCF change	—	—	—	New“FY25 Adjusted FCF increasing ~$120MM (~20%) from original plan”	—	—	—	—
Adjusted FCF improvement vs. February outlook	—	—	—	New“a ~20% improvement in Adjusted FCF”	—	—	—	—
Adjusted FCF per share improvement vs. February outlook	—	—	—	New“~25% improvement in Adjusted FCF per share vs. the February outlook (normalized for commodity pricing)”	—	—	—	—
Adjusted Free Cash Flow	—	New“$860MM”	Lowered“approximately $650MM”	—	—	—	—	—
Average working interest of TIL wells	—	New“approximately 80%”	—	—	—	—	—	—
Base dividend	—	—	—	—	New“$1.30 per share”	—	—	—
Base Dividend	—	—	—	New“$1.30 per share of common stock”	—	—	—	—
Base dividend per share	—	New“$1.30 per share”	—	—	—	—	—	—
CapEx	—	—	—	—	New“$1.35B”	—	—	—
Capital expenditures	New“$1.4B”	—	—	—	—	—	—	—
Cash G&A	—	—	—	—	New“$90MM”	—	—	—
Cash G&A ($MM)	—	New“$97.0 – $107.0”	Reiterated“$97.0 – $107.0”	Lowered“$90 – $100”	Lowered“$87 – $92”	—	—	—
Cash G&A ($MM)	—	—	New“$26.0 – $28.0”	—	—	—	—	—
Cash G&A ($MM) (1)	—	New“$29.0 – $31.0”	—	—	—	—	—	—
Cash G&A ($MM) (1)	—	New“$97.0 – $107.0”	—	—	—	—	—	—
Cash G&A ($MM) (2)	New“$29.0 – $31.0”	—	—	—	—	—	—	—
Cash GPT ($/Boe)	—	New“$2.65 – $3.15”	Narrowed“$2.70 – $3.10”	Narrowed“$2.80 – $3.05”	Narrowed“$2.85 – $2.92”	—	—	—
Cash GPT ($/Boe)	—	—	New“$2.65 – $3.15”	—	—	—	—	—
Cash GPT ($/Boe) (1)	—	New“$2.65 – $3.15”	—	—	—	—	—	—
Cash GPT ($/Boe) (2)	New“$2.60 – $3.20”	—	—	—	—	—	—	—
Cash Interest	—	—	—	—	New“$79MM”	—	—	—
Cash Interest ($MM)	—	New“$51.0 – $59.0”	Raised“$65.0 – $71.0”	Raised“$68 – $72”	Raised“$78 – $80”	—	—	—
Cash Interest ($MM)	—	—	New“$16.5 – $18.5”	—	—	—	—	—
Cash Interest ($MM) (1)	—	New“$15.0 – $17.0”	—	—	—	—	—	—
Cash Interest ($MM) (1)	—	New“$51.0 – $59.0”	—	—	—	—	—	—
Cash Interest ($MM) (2)	New“$18.0 – $20.0”	—	—	—	—	—	—	—
Cash Taxes	—	—	—	New“3.5% – 6.5%%”	—	—	—	—
E&P & Other CapEx ($MM)	—	New“$1,340 – $1,460”	Lowered“$1,325 – $1,415”	Lowered“$1,320 – $1,380”	Narrowed“$1,350 – $1,380”	—	—	—
E&P & Other CapEx ($MM)	New“$315 – $355”	Raised“$350 – $380”	Raised“$355 – $385”	—	—	—	—	—
E&P & Other CapEx (three-year outlook)	New“$1.4B”	—	—	—	—	—	—	—
E&P and Other CapEx	—	—	New“approximately $1.37B”	Lowered“Lowered -$20MM to $1.35B at midpoint”	—	—	—	—
E&P and other CapEx at midpoint of	—	New“$1.4B”	—	—	—	—	—	—
FY25 midpoint CapEx	—	New“$1.4B”	—	—	—	—	—	—
FY25 midpoint oil volumes	—	New“152.5 MBopd”	—	—	—	—	—	—
FY25 non-operated CapEx at midpoint	—	New“$215MM”	—	—	—	—	—	—
Gross Operated TILs	—	—	New“130 – 150”	—	—	—	—	—
Gross Operated TILs	—	—	New“40 – 50”	—	—	—	—	—
Gross Operated TILs	—	—	New“130 – 150 wells (~80% working interest)”	—	—	—	—	—
Gross Operated TILs	—	—	New“40 – 50 wells planned for 2Q25 (~73% working interest)”	—	—	—	—	—
Gross operated TILs (~80% working interest)	—	—	—	—	New“115 – 125”	—	—	—
Gross operated wells	—	—	—	New“115 – 135”	Narrowed“115 – 125”	—	—	—
Gross operated wells to TIL	—	New“130 – 150”	—	—	—	—	—	—
Gross operated wells to TIL	—	New“22 – 32”	—	—	—	—	—	—
LOE	—	—	New“$9.60/Boe”	Reiterated“$9.60/Boe”	Raised“$9.73/Boe”	—	—	—
LOE ($/Boe)	—	—	New“$9.20 – $10.00”	Narrowed“$9.35 – $9.85”	Narrowed“$9.60 – $9.85”	—	—	—
LOE ($/Boe)	New“$9.25 – $10.25”	Raised“$9.40 – $10.40”	Lowered“$9.25 – $10.25”	—	—	—	—	—
Natural Gas Realization (% of Henry Hub)	—	New“35% – 45%”	Narrowed“36% – 44%”	Narrowed“36% – 41%”	Narrowed“38% – 40%”	—	—	—
Natural Gas Realization (% of Henry Hub)	New“25% – 35%”	Raised“45% – 55%”	Lowered“25% – 35%”	—	—	—	—	—
Natural Gas Volumes (MMcfpd)	—	New“415.5 – 428.5”	Narrowed“417.1 – 426.9”	Raised“423.1 – 430.7”	Lowered“420.4 – 423.4”	—	—	—
Natural Gas Volumes (MMcfpd)	New“395.5 – 408.5”	Raised“402.0 – 415.0”	Raised“408.5 – 421.5”	—	—	—	—	—
NGL and natural gas realizations trend vs FY25 midpoint	—	New“above the FY25 midpoint in 1Q25 and 4Q25 and below the FY25 midpoint in 2Q25 and 3Q25”	—	—	—	—	—	—
NGL Realization (% of WTI)	—	New“9% – 19%”	Narrowed“10% – 18%”	Narrowed“11% – 16%”	Lowered“10% – 13%”	—	—	—
NGL Realization (% of WTI)	New“5% – 15%”	Raised“13% – 23%”	Lowered“5% – 15%”	—	—	—	—	—
NGL Volumes (MBblpd)	—	New“47.8 – 49.3”	Narrowed“48.0 – 49.1”	Raised“50.2 – 52.5”	Raised“51.7 – 52.7”	—	—	—
NGL Volumes (MBblpd)	New“46.1 – 47.6”	Raised“46.8 – 48.3”	Raised“47.3 – 48.8”	—	—	—	—	—
Non-operated CapEx	—	New“$215MM”	—	—	—	—	—	—
Oil Differentials	—	—	—	New“Narrowed by $0.30/Bbl”	—	—	—	—
Oil Discount to WTI ($/Bbl)	—	New“$(2.75) – $(0.75)”	Narrowed“$(2.70) – $(1.20)”	Raised“$(2.15) – $(1.15)”	Narrowed“$(2.15) – $(1.65)”	—	—	—
Oil Discount to WTI ($/Bbl)	New“$(2.00) – $0.00”	Lowered“$(3.00) – $(1.00)”	Lowered“$(3.05) – $(1.05)”	—	—	—	—	—
Oil Volumes	New“152 MBopd – 153 MBopd”	Reiterated“152 MBopd – 153 MBopd”	Narrowed“152.5 MBopd”	Raised“Raised +500 Bopd to 153.0 MBopd at midpoint”	—	—	—	—
Oil volumes (excluding XTO Acquisition)	—	—	—	—	New“153.3 MBopd”	—	—	—
Oil Volumes (MBopd)	—	New“150.3 – 154.8”	Narrowed“151.0 – 154.0”	Raised“151.8 – 154.1”	Raised“153.8 – 154.8”	—	—	—
Oil Volumes (MBopd)	New“149.5 – 154.5”	Narrowed“149.5 – 152.5”	Raised“153.0 – 156.0”	—	—	—	—	—
Oil Volumes (three-year outlook, flat pro forma FY24)	New“152 MBopd – 153 MBopd”	—	—	—	—	—	—	—
Oil Volumes impact from recent A&D activity	New“approximately 0.4 MBopd”	—	—	—	—	—	—	—
Oil volumes trend 2Q25 vs 1Q25	—	New“slightly up compared to 1Q25”	—	—	—	—	—	—
Oil volumes trend into 3Q25	—	New“further growth”	—	—	—	—	—	—
Production Taxes (% of Oil, NGL and Natural Gas Sales)	—	New“8.4% – 8.8%”	Lowered“7.8% – 8.2%”	Lowered“7.6% – 7.8%”	Narrowed“7.6% – 7.7%”	—	—	—
Production Taxes (% of Oil, NGL and Natural Gas Sales)	New“8.7% – 9.1%”	Lowered“8.3% – 8.7%”	Widened“8.3% – 8.8%”	—	—	—	—	—
TIL gross operated wells	—	—	—	New“115 – 135 gross operated wells (~80% working interest)”	—	—	—	—
Total Volumes (MBoepd)	—	New“267.3 – 275.5”	Narrowed“268.5 – 274.2”	Raised“272.5 – 278.3”	Narrowed“275.6 – 278.1”	—	—	—
Total Volumes (MBoepd)	New“261.5 – 270.1”	Narrowed“263.3 – 269.9”	Raised“268.3 – 275.0”	—	—	—	—	—
For FY2024
Adjusted EBITDA	New“approximately $2.7B”	—	—	—	—	—	—	—
Cash Tax (% of Adjusted EBITDA)	New“2% – 4%”	—	—	—	—	—	—	—
Cash Tax (% of Adjusted EBITDA) (3)	New“2% – 4%”	—	—	—	—	—	—	—
Adjusted Free Cash Flow	New“$1.1B”	—	—	—	—	—	—	—
CapEx	—	New“$1.4B”	—	—	—	—	—	—
Cash G&A ($MM)	New“$116.2 – $118.2”	—	—	—	—	—	—	—
Cash G&A ($MM) (2)	New“$116.2 – $118.2”	—	—	—	—	—	—	—
Cash GPT ($/Boe)	New“$3.11 – $3.25”	—	—	—	—	—	—	—
Cash GPT ($/Boe) (2)	New“$3.11 – $3.25”	—	—	—	—	—	—	—
Cash Interest ($MM)	New“$62.7 – $64.7”	—	—	—	—	—	—	—
Cash Interest ($MM) (2)	New“$62.7 – $64.7”	—	—	—	—	—	—	—
E&P & Other CapEx	New“$1.48B”	—	—	—	—	—	—	—
E&P & Other CapEx ($MM)	New“$1,460 – $1,500”	—	—	—	—	—	—	—
FY24 oil volumes	—	New“152.5 MBopd”	—	—	—	—	—	—
LOE ($/Boe)	New“$9.38 – $9.63”	—	—	—	—	—	—	—
Natural Gas Realization (% of Henry Hub)	New“34% – 36%”	—	—	—	—	—	—	—
Natural Gas Volumes (MMcfpd)	New“407.6 – 410.9”	—	—	—	—	—	—	—
NGL Realization (% of WTI)	New“9% – 11%”	—	—	—	—	—	—	—
NGL Volumes (MBblpd)	New“47.7 – 48.1”	—	—	—	—	—	—	—
Oil Discount to WTI ($/Bbl)	New“$(1.75) – $(1.25)”	—	—	—	—	—	—	—
Oil Volumes (FY24 pro forma midpoint)	New“152.7 MBopd”	—	—	—	—	—	—	—
Oil Volumes (MBopd)	New“152.0 – 153.3”	—	—	—	—	—	—	—
Oil volumes at midpoint of (as labeled in filing)	—	New“152.5 MBopd”	—	—	—	—	—	—
Pro forma capital	New“$1.48B”	—	—	—	—	—	—	—
Production Taxes (% of Oil, NGL and Natural Gas Sales)	New“8.8% – 8.9%”	—	—	—	—	—	—	—
Reinvestment rate	New“less than 60%”	—	—	—	—	—	—	—
Total Volumes (MBoepd)	New“267.6 – 269.8”	—	—	—	—	—	—	—
No period stated
Base dividend	New“$1.25 per share of common stock”	Raised“$1.30 per share of common stock”	Reiterated“$1.30 per share”	Reiterated“$1.30 per share”	—	Reiterated“$1.30 per share”	Reiterated“$1.30 per share”	Reiterated“$1.30 per share”
Base-plus-variable cash dividend	New“$1.44 per share of common stock”	—	—	—	—	—	—	—
Dividend payment date	New“December 12, 2024”	Raised“March 26, 2025”	—	—	—	—	—	—
E&P and other CapEx	—	New“$1.4B”	—	—	—	—	—	—
Marketing optimization annualized FCF savings	—	—	—	—	New“$30MM-$50MM”	—	—	—
Next borrowing base redetermination	—	New“in or around October 2025”	—	—	—	—	—	—
Share Repurchase Program Authorization	New“$750MM”	—	—	Raised“$1B”	—	—	—	—
Synergies from Enerplus combination	New“over $200MM”	—	—	—	—	—	—	—
Three-year outlook CapEx (annual)	—	New“$1.4B”	—	—	—	—	—	—
Three-year outlook oil volumes	—	New“152 MBopd – 153 MBopd”	—	—	—	—	—	—
Variable dividend	New“$0.19 per share of common stock”	—	—	—	—	—	—	—

Values in quotation marks are the company’s words. Change labels compare each statement with the same metric and target year in the previous release. HighGravityData does not judge whether guidance was met.