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Designed covers and liners to prevent AMD from waste rock; Monthly monitoring showed sulfate and Fe spikes typical of AMD; Budget includes a lime treatment plant to neutralize AMD.

Swapping to ESPs lifted output 30% in low-pressure wells; Gas-lift valves were optimized to handle high GOR; Rod pump retrofits cut LOE in the mature field.

We recognized ARO for platform removal and subsea P&A; ARO accretion expense hit the income statement; Deal valuation adjusted for ARO on legacy wells.

Fire assays returned 2.1 g/t Au across the main zone; Blanks and standards passed assay QA/QC; Turnaround time from the external lab is 7 days.

Company averaged 50 MBOE/d with 60% liquids; 2P reserves total 120 MMBOE; LOE improved to $8/BOE after compression.

The BOP passed a 10,000-psi pressure test; The crew shut the annular preventer when a gas kick was detected; Regulators audited BOP maintenance records.

The shale program’s breakeven is ~$45/bbl; Pit design targeted a higher breakeven cutoff grade; The LNG train remains cash-breakeven at $2.50/MMBtu.

2026 CAPEX is front-loaded into FEED and long-lead items; CAPEX per flowing BOE fell 15% year over year; Stage-gate controls were tightened to curb CAPEX creep.

Hub-and-spoke CCUS model targets 1 Mtpa; Pore-space rights secured for saline storage; Tax credits materially improve CCUS economics.

Cut-off raised to 0.60% Cu under weaker prices; Blocks below cutoff were excluded from reserves; PEA includes cutoff sensitivity tables.

Hyperbolic b-factor of 0.8 fits first 36 months; PDP valuation relies on DCA under SEC guidance; History match improved after water-handling upgrades.

P&A calls for cement plugs isolating all aquifers; The decommissioning plan staggers platform removals; A trust fund was set up to meet P&A obligations.

Narrower stopes cut dilution to 10%; A dilution factor is applied in the reserve statement; Ore control drilling reduced dilution in saprolite.

Polymer EOR raised sweep efficiency in the flood; CO2 miscible injection yielded 12% incremental recovery; Steam EOR economics hinge on gas prices.

Awarded EPC for the greenfield concentrator; Chose EPCM for complex brownfield tie-ins; Risk allocation and LDs differ under EPC vs EPCM.

ESG-linked revolver margin tied to emissions; Community agreements are central to ESG strategy; Board ESG committee oversees tailings risk.

Type-curve median EUR is 800 MBOE; EURs were revised up after recompletions; EUR distribution drives drilling inventory value.

The farm-in carries two exploration wells to casing point; We farmed out 50% of Block 3 to share risk; Earn-in is contingent on seismic quality.

We committed to zero routine flaring by 2030; New gathering reduced flare volumes by 70%; Flaring permits are limited to upsets only.

Topsides capacity is 150 kbopd with gas reinjection; Leasing an FPSO reduces upfront CAPEX; A turret mooring allows weathervaning.

FEED includes PFDs, heat balances, and plot plans; Class 3 estimate accuracy is ±15%; Procurement strategies are locked at FEED exit.

Rougher-scavenger-cleaner circuit hit 88% Cu recovery; Reagent suite optimized with xanthates and frothers; Column cells added to improve concentrate grade.

Rising GOR indicates gas breakthrough; Separators were sized for 2,000 scf/bbl GOR; Flaring reductions require better GOR management.

Domains mapped for hardness and recovery variability; Geomet models inform mill throughput and blending; Early geomet data de-risked process design.

Gamma and resistivity guided landing in the sweet spot; Out-of-zone footage fell 40% with geosteering; Azimuthal tools improved fracture targeting.

Agglomeration improved permeability and kinetics; Stack height was limited by heap stability; PLS routed to SX-EW for copper recovery.

Collars hedge 50% of 2026 oil volumes; Basis hedges protect the WCS differential; Hedge policy caps downside while retaining upside.

TRIR and near-miss rates are core HSE KPIs; HSE audits flagged confined-space controls; HSEMS aligned with ISO 14001 and 45001.

Slickwater frac at 2,000 lb/ft proppant loading; Zipper fracs improved stage efficiency; Frac gradient constrained pump schedule.

ISR wellfields were rolled out in phases; Lixiviant chemistry optimized selectivity; ISR minimized surface disturbance versus pits.

After-tax IRR is 18% at $75/bbl; IRR sensitivity shows exposure to CAPEX overruns; Hurdle IRR for greenfield is 15%.

The operator is designated under the JOA; AFE approval requires 65% voting interest; Non-consent penalties are defined in the JOA.

Resource upgraded to JORC Indicated category; The Competent Person signed JORC Table 1; JORC-compliant MRE was released to the market.

Mud weight was raised after a gas kick; Shut-in drillpipe pressure was monitored during the kill; Crews practice kick drills weekly.

LOE dropped to $8/BOE after compression; Workover costs were charged to LOE; Benchmarking LOE identified high-cost pads.

LWD gamma/resistivity guided the horizontal landing; MWD surveys were taken every stand; Mud-pulse telemetry limited data bandwidth.

Copper offtake priced at LME cash minus TC/RC; Hedged aluminum exposure on LME futures; Lower LME stocks tightened premiums.

LOM extended to 15 years after reserve growth; Pushback sequencing optimized LOM cash flow; Closure costs are provisioned across the LOM.

Higher NGL yield improved field netbacks; The frac spread drives NGL margins; NGL takeaway expanded with a new fractionator.

Differential widened, reducing Canadian netbacks; Field netback beat corporate netback on lower tariffs; Upgrading liquids improved condensate netbacks.

Filed an NI 43-101 PFS on SEDAR+; The Qualified Person reviewed all assay QA/QC; NI 43-101 limits use of Inferred in economic studies.

Secured an offtake to finance the concentrator; Take-or-pay terms underpin throughput; Offtaker lifts product FOB at the terminal.

OPEX per ton milled fell 10% after debottlenecking; Power dominates OPEX in SAGD projects; OPEX budgeting is tied to throughput.

Core shows 15% porosity, 200 mD permeability; Tight sands need fracs due to low perm; Net pay cutoffs include porosity thresholds.

PSC caps cost recovery at 60% of gross; Profit split varies with the R-factor; Local content targets are embedded in the PSC.

QA/QC inserts include blanks, standards, and duplicates; Chain-of-custody was logged from rig to lab; QA/QC review flagged analytical drift at the lab.

Booked 2P reserves of 120 MMBOE; Volumes moved from 3P to 2P after appraisal; PDP/PUD breakdown given in the reserve report.

4D seismic tracked the waterflood front; A new 3D reduced structural uncertainty beneath salt; Seismic inversion refined net pay mapping.

SOR improved to 2.7 with better insulation; New pads expanded SAGD capacity by 10 kbopd; Cogeneration cut steam costs and emissions.

Converted to filtered tailings to reduce risk; Independent audit under TSM confirmed dam safety; Deposition plan manages beach slopes and water balance.