HighGravityDataCoterra Energy — Nov 3, 2025 release
Fiscal 2025 third-quarter results · 8-K Item 2.02 · Exhibit 99.1 · 0000858470-25-000196
Showing in the filing
Drilling and completion Permian Basin
“$1,560”
Period
FY2025
Measure
Company-defined measure
Source
Guidance table
All guidance in this release · 53
Quarterly dividend for Q4 FY2025
“$0.22 per share”
WTI ($ per bbl) for FY2025
“$65”
Capital expenditures (non-GAAP) for FY2025
“around $2.3 billion”
Reinvestment rate for FY2025
“approximately 55%”
Free Cash Flow (non-GAAP) for FY2025
“approximately $2.0 billion”
Capital expenditures for FY2026
“modestly down from 2025”
Annual BOE growth for FY2026
“0-5%”
Annual oil growth for FY2026
“approximately 5%”
Reinvestment rate for FY2026
“at, or below, 50%”
Per unit costs for Q4 FY2025
“expects fourth quarter per unit costs to trend closer to the mid-point of our annual guidance range”
Share repurchases for Q4 FY2025
“expects to continue to opportunistically repurchase its shares”
Shareholder returns
“50% or greater of Free Cash Flow (non-GAAP)”
Shareholder returns (% of Free Cash Flow) for the long term
“50% or greater”
Total equivalent production for FY2025
“772 to 782 MBoepd”
Natural gas production for FY2025
“2,925 to 2,965 MMcfpd”
Oil production for FY2025
“159 to 161 MBopd”
Total equivalent production for FY2025
“770 to 810 MBoepd”
Total equivalent production for Q4 FY2025
“770 to 810 MBoepd”
Oil production for FY2025
“172 to 178 MBopd”
Oil production for Q4 FY2025
“172 to 178 MBopd”
Natural gas production for FY2025
“2,775 to 2,925 MMcfpd”
Natural gas production for Q4 FY2025
“2,775 to 2,925 MMcfpd”
Capital expenditures (non-GAAP) for FY2025
“approximately $530 million”
Capital expenditures (non-GAAP) for Q4 FY2025
“approximately $530 million”
Capital expenditures Total Company ($ in mil… for Q4 FY2025
“$530”
Effective tax rate for FY2025
“22%”
Cash taxes for Q4 FY2025
“no cash taxes during fourth-quarter 2025”
Net wells turned in line Anadarko Basin for FY2025
“20”
Total Equivalent Production (MBoed) for FY2025
“772 — 777 — 782”
Gas (Mmcf/day) for FY2025
“2,925 — 2,945 — 2,965”
Oil (MBbl/day) for FY2025
“159 — 160 — 161”
Net wells turned in line Marcellus Shale for FY2025
“9 — 13”
Net wells turned in line Permian Basin for FY2025
“165”
Net wells turned in line Anadarko Basin for Q4 FY2025
“5”
Capital expenditures Total Company ($ in mil… for FY2025
“$2,310”
Drilling and completion Marcellus Shale for FY2025
“$320”
Drilling and completion Permian Basin for FY2025
“$1,560”
Drilling and completion Anadarko Basin for FY2025
“$230”
Midstream, saltwater disposal and infrastruc… for FY2025
“$200”
Discretionary Cash Flow ($ in billions) for FY2025
“$4.3”
Capital Expenditures ($ in billions) for FY2025
“$2.3”
Free Cash Flow (DCF - incurred capex) ($ in … for FY2025
“$2.0”
Lease operating expense + workovers + region… for FY2025
“$2.50 — $3.05 — $3.60”
Henry Hub ($ per mmbtu) for FY2025
“No change”
Gathering, processing, & transportation ($/b… for FY2025
“$3.25 — $3.75 — $4.25”
Taxes other than income ($/boe) for FY2025
“$1.25 — $1.50 — $1.75”
General & administrative ($/boe) for FY2025
“$0.90 — $1.00 — $1.10”
Unit Operating Cost ($/boe) for FY2025
“$7.90 — $9.30 — $10.70”
Total Equivalent Production (MBoed) for Q4 FY2025
“770 — 790 — 810”
Gas (Mmcf/day) for Q4 FY2025
“2,775 — 2,850 — 2,925”
Oil (MBbl/day) for Q4 FY2025
“172 — 175 — 178”
Net wells turned in line Marcellus Shale for Q4 FY2025
“2 — 6”
Net wells turned in line Permian Basin for Q4 FY2025
“41”
Exhibit 99.1 · the passage around this item
… earlier in the release
Full Year Guidance 2025 Guidance (February) Updated 2025 Guidance Low Mid High Low Mid High Total Equivalent Production (MBoed) 710 — 740 — 770 772 — 777 — 782 Gas (Mmcf/day) 2,675 — 2,775 — 2,875 2,925 — 2,945 — 2,965 Oil (MBbl/day) 152 — 160 — 168 159 — 160 — 161 Net wells turned in line Marcellus Shale 10 — 13 — 15 9 — 13 Permian Basin 150 — 158 — 165 165 Anadarko Basin 15 — 20 — 25 20 Capital expenditures ($ in millions) Total Company $2,100 — $2,250 — $2,400 $2,310 Drilling and completion Marcellus Shale $250 midpoint $320 Permian Basin $1,570 midpoint $1,560 Anadarko Basin $230 midpoint $230 Midstream, saltwater disposal and infrastructure $200 midpoint $200 Commodity price assumptions: WTI ($ per bbl) $71 $65 Henry Hub ($ per mmbtu) $4.22 $3.41 Cash Flow & Investment ($ in billions) Discretionary Cash Flow $5.0 $4.3 Capital Expenditures $2.1 — $2.3 — $2.4 $2.3 Free Cash Flow (DCF - incurred capex) $2.7 $2.0 $ 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 20 Quarterly Guidance Third Quarter 2025 Guidance Third Quarter 2025 Actual Fourth Quarter 2025 Guidance Low Mid High Low Mid High Total Equivalent Production (MBoed) 740 — 765 — 790 785.0 770 — 790 — 810 Gas (Mmcf/day) 2,750 — 2,825 — 2,900 2,894.6 2,775 — 2,850 — 2,925 Oil (MBbl/day) 158 — 163 — 168 166.8 172 — 175 — 178 Net wells turned in line M
later in the release …
the item shown at left
other guidance in this release
Text is the filed exhibit, verbatim.