HighGravityDataCoterra Energy — Aug 4, 2025 release
Fiscal 2025 second-quarter results · 8-K Item 2.02 · Exhibit 99.1 · 0000858470-25-000162
Showing in the filing
Total Equivalent Production (MBoed)
“740 — 765 — 790”
Period
Q3 FY2025
Measure
Company-defined measure
Source
Guidance table
All guidance in this release · 39
Quarterly Dividend for Q3 FY2025
“$0.22 per share”
Free Cash Flow (non-GAAP) for FY2025
“$2.1 billion”
Share Repurchase Authorization Remaining
“$1.1 billion”
Shareholder Return Target (Dividends + Buyba… for the long term
“50% or greater of annual Free Cash Flow (non-GAAP)”
Shareholder returns
“50% or greater of annual Free Cash Flow (non-GAAP)”
Term Loan Repayment Target for FY2025
“$650 million”
Capital expenditures (non-GAAP) for FY2025
“approximately $2.3 billion”
Total equivalent production for FY2025
“740 to 790 MBoepd”
Total Equivalent Production for Q3 FY2025
“740 to 790 MBoepd”
Oil production for FY2025
“158 to 168 MBopd”
Oil Production for Q3 FY2025
“158 to 168 MBopd”
Natural gas production for FY2025
“2,750 to 2,900 MMcfpd”
Natural Gas Production for Q3 FY2025
“2,750 to 2,900 MMcfpd”
Capital expenditures (non-GAAP) for FY2025
“$625 to $675 million”
Capital Expenditures (non-GAAP) for Q3 FY2025
“$625 to $675 million”
Effective tax rate for FY2025
“22%”
Current tax (% of effective tax rate) for FY2025
“40% to 60%”
Current Tax Percentage for FY2025
“40% to 60%”
New Permian Power Netback Gas Sale Volume for FY2028
“50 MMcf per day for a seven-year term”
Net wells turned in line Marcellus Shale for Q3 FY2025
“4”
Net wells turned in line Anadarko Basin for Q3 FY2025
“6”
Commodity price assumption - WTI ($ per bbl) for FY2025
“$66”
Total Equivalent Production (MBoed) for FY2025
“755 — 768 — 780”
Gas (Mmcf/day) for FY2025
“2,875 — 2,913 — 2,950”
Oil (MBbl/day) for FY2025
“157 — 160 — 163”
Capital expenditures Total Company ($ in mil… for FY2025
“$2,100 — $2,200 — $2,300”
Drilling and completion - Marcellus Shale (m… for FY2025
“$350”
Drilling and completion - Permian Basin (mid… for FY2025
“$1,520”
Drilling and completion - Anadarko Basin (mi… for FY2025
“$230”
Midstream, saltwater disposal and infrastruc… for FY2025
“$200”
Commodity price assumption - Henry Hub ($ pe… for FY2025
“$3.67”
Discretionary Cash Flow ($ in billions) for FY2025
“$4.4”
Capital Expenditures ($ in billions) for FY2025
“$2.1 — $2.2 — $2.3”
Free Cash Flow (DCF - incurred capex) ($ in … for FY2025
“$2.1”
Total Equivalent Production (MBoed) for Q3 FY2025
“740 — 765 — 790”
Gas (Mmcf/day) for Q3 FY2025
“2,750 — 2,825 — 2,900”
Oil (MBbl/day) for Q3 FY2025
“158 — 163 — 168”
Net wells turned in line Permian Basin for Q3 FY2025
“40 — 45 — 50”
Capital expenditures Total Company ($ in mil… for Q3 FY2025
“$625 — $650 — $675”
Exhibit 99.1 · the passage around this item
… earlier in the release
Full Year Guidance 2025 Guidance (February) Updated 2025 Guidance Low Mid High Low Mid High Total Equivalent Production (MBoed) 710 — 740 — 770 755 — 768 — 780 Gas (Mmcf/day) 2,675 — 2,775 — 2,875 2,875 — 2,913 — 2,950 Oil (MBbl/day) 152 — 160 — 168 157 — 160 — 163 Net wells turned in line Marcellus Shale 10 — 13 — 15 No change Permian Basin 150 — 158 — 165 No change Anadarko Basin 15 — 20 — 25 No change Capital expenditures ($ in millions) Total Company $2,100 — $2,250 — $2,400 $2,100 — $2,200 — $2,300 Drilling and completion Marcellus Shale $250 midpoint $350 Permian Basin $1,570 midpoint $1,520 Anadarko Basin $230 midpoint $230 Midstream, saltwater disposal and infrastructure $200 midpoint $200 Commodity price assumptions: WTI ($ per bbl) $71 $66 Henry Hub ($ per mmbtu) $4.22 $3.67 Cash Flow & Investment ($ in billions) Discretionary Cash Flow $5.0 $4.4 Capital Expenditures $2.1 — $2.3 — $2.4 $2.1 — $2.2 — $2.3 Free Cash Flow (DCF - incurred capex) $2.7 $2.1 $ per boe, unless noted: Lease operating expense + workovers + region office $2.50 — $3.05 — $3.60 No change Gathering, processing, & transportation $3.25 — $3.75 — $4.25 No change Taxes other than income $1.25 — $1.50 — $1.75 No change General & administrative (1) $0.90 — $1.00 — $1.10 No change Unit Operating Cost $7.90 — $9.30 — $10.70 No change _______________________________________________________________________________ (1) Excludes stock-based compensation and severance expense 21 Quarterly Guidance Second Quarter 2025 Guidance Second Quarter 2025 Actual Third Quarter 2025 Guidance Low Mid High Low Mid High Total Equivalent Production (MBoed) 710 — 735 — 760 783.9 740 — 765 — 790 Gas (Mmcf/day) 2,700 — 2,775 — 2,850 2,998.6 2,750 — 2,825 — 2,900 Oil (MBbl/day) 147 — 152 — 157 155.4 158 — 163 — 168 Net wells turned in line Marcellus Shale 3 3 4 Permian Basin 45 — 55 — 65 49 40 — 45 — 50 Anadarko Basin 9 9 6 Capital expenditures ($ in millions) Total Company $575 — $613 — $650 $569 $625 — $650 — $675 22 Investor Contact Daniel Guffey - Vice President of Finance, IR & Treasurer 281.589.4875 Hannah Stuckey - Investor Relations Manager 281.589.4983 23
the item shown at left
other guidance in this release
Text is the filed exhibit, verbatim.