FieldState reviews every brownfield well on a recurring cadence and turns production signals into an evidence-backed action backlog: monitor, fix data, validate, or approve intervention.
See the asset-level backlog first, then drill into the well-level evidence.
Example values shown for layout only. Production economics are calculated from operator-provided assumptions and evidence available in the review.
Start with the data you already have. Each review turns new signals into decisions your team can act on.
Monthly oil, water and gas by well, producing days, uptime, downtime and field records already in your files.
Rates are normalized, active days are checked, clean intervals are selected, and DCA segments are qualified before economics are calculated.
Restarts, shut-ins, regime shifts, downtime, water-cut changes, GOR/WOR shifts and validation gaps are surfaced.
Monitor, data-fix, DCA review, status check, validation and intervention candidates are ranked in one backlog.
You see Basic NPV, IRR, Economic Limit Date, deferred production, CO₂ intensity, cost of waiting and review-ready evidence.
Each ranked row opens into a reviewable candidate card with economics, evidence, required validation and a clear next owner.
Production, downtime, lift context and field records are checked on a recurring cadence.
Every well is screened, explained and ranked with preliminary economics, evidence and required validation.
Asset, operations, finance and engineering teams review the same monthly candidate list.
Example values shown for layout only. Production economics are calculated from operator-provided assumptions and evidence available in the review.
FieldState economics are designed to rank, defer and validate production actions. They help your team decide which wells deserve attention now, which need field validation first, and which should not receive service spend yet.
These are screening-level economics for prioritizing, validating and deferring production actions. Final reserves, AFE and certified emissions workflows remain with your existing operator controls.
Directional net present value using operator-provided price, cost, intervention and decline assumptions.
Simple return screen where forecast response and intervention cost make the calculation meaningful.
Estimated date when the well falls below the economic cutoff under the selected assumptions.
Simple cost-of-waiting estimate for delayed validation or delayed intervention.
A kg/bbl screening metric for portfolio context, tie-breaks and marginal-well review.
Oil price, discount rate, lifting cost, water cost, fixed OPEX, intervention cost and CO₂ factors stay visible.
FieldState does not promote a well to action because one number looks good. Each candidate is gated by data quality, active-day logic, selected DCA intervals, fit confidence, status history and required field evidence.
FieldState is a recurring production decision review for brownfield operators. It turns existing production, uptime and field records into a ranked action backlog with preliminary economics, evidence gates and owner-ready next steps.
Each well is screened repeatedly as new production, downtime, restart and validation evidence arrives.
Basic NPV, IRR, Economic Limit Date, deferred production and CO₂ intensity help prioritize what deserves attention now.
Data quality, active-day logic, selected DCA intervals, fit confidence and field evidence determine whether a case moves to action or validation.
Oil price, discount rate, lifting cost, water cost, fixed OPEX, intervention cost and CO₂ factors stay visible beside the result.
Validated candidates carry the reason, economics, required evidence, suggested next step and owner before field or service dollars are committed.
FieldState provides screening-level decision support. Final technical, financial and commercial approvals remain with the operator's existing controls.
At any single point in time, many wells have nothing defensible to improve. Your first report typically surfaces around 5% of wells as current candidates. Continuous review follows the lifecycle of each well, so your opportunity pool can reach up to 30% as new production, downtime, restarts and validation evidence arrive.
Your one-time report is useful, but it mostly catches wells that are already visible in the loaded history.
As your new months, restarts, downtime, water-cut shifts and validation events arrive, more candidates become visible and defensible.
Opportunity pool means wells that become defensible candidates for monitoring, data fix, validation or intervention review over time. It does not mean 30% of wells become immediate workover candidates.
Your existing monthly oil, water and gas by well create the first economic and physics read.
New production, downtime, restarts, water-cut shifts and validation gaps are watched as they appear.
Your ranked candidate list is refreshed with economics, required evidence and owner-ready next steps.
You get coverage, value captured, value at risk and the current portfolio stance.
FieldState gives operations and procurement a defensible handoff before service dollars are committed: why this well, why now, what to validate and what is ready for approval.
The production signal, status change, DCA segment and economic screen that put the well into the backlog.
Cost of waiting, deferred production, economic limit timing and urgency behind the recommendation.
The field evidence required before a service request, workover scope or intervention decision is approved.
Candidates with weak data, weak economics or missing validation stay out of service spend until the case is defensible.
You do not need a new sensor program or a data lake to begin. Missing records lower the evidence grade and create validation tasks; they do not block the first review.
Your report opens with the recommended stance, headline KPIs, uncertainty range and regime-shift timeline. The pages underneath show exactly why the recommendation was made.
Your leadership gets the conclusion first. Your engineers can drill into source data, formulas, segments and proxy assumptions before trusting the recommendation.
Recommended stance, value, urgency, owner and reason the prior read no longer applies.
Production coverage, data-quality gates, selected intervals and excluded periods stay visible.
DCA fits, economic inputs, segment choices, Basic NPV, IRR and confidence measures sit beside the result.
Directional phase and rel-perm proxies are marked as proxies, not reservoir-model claims.
The technical pages let the operator trace the recommendation back to the underlying numbers.
Leadership, engineering and operations review the same calculation chain at different levels of detail.
Value at risk, Basic NPV, IRR, Economic Limit Date, payback and portfolio stance.
Source data, active days, data-quality gates, selected intervals, excluded periods, DCA fits, formulas and proxy assumptions.
Validation queue, field checks, service-priority handoff, required evidence and next owner.
Your engineer can follow the same case from raw production to final stance. The goal is not to hide the calculation. The goal is to make the decision reviewable.
Your engineers can check the data quality, selected intervals, decline fits, uncertainty, economics and assumptions before approving field work.
Fits exponential and harmonic screens to the latest three producing months and projects them to the economic cut-off. Includes well metadata, fit confidence, and the “validate then convert” guardrail (restart, uptime, refit) so a single hot month does not become an action case.
Operator-tunable inputs — oil price, discount rate, water cost, lifting cost, fixed OPEX, intervention cost and CO₂ factor — drive a live recompute of Basic NPV, IRR, Economic Limit Date, deferred production, payback and economic life. The DCA evidence does not move; the economics around it do.
States the calculation path up front: normalize production, check active days, qualify clean decline windows, flag anomalies, fit DCA only on validated intervals, and treat economics as a screening read until field evidence supports action.
Normalizes oil, water and gas to comparable daily rates, then surfaces water-cut, WOR and GOR. The point is to separate real decline from a phase shift before drawing any conclusion.
Filters restarts, shut-ins, partial months and one-month spikes so the DCA fit lands on a physically stable decline window. If the chosen interval contains an outlier, the report tells the engineer to rebuild the interval before trusting the fit.
Compares every clean segment in the well’s history — absolute and normalized — so engineers can see whether the current decline is structurally different from earlier producing periods.
Refits each clean segment as both exponential and harmonic. The fan of forecasts gives a defensible range for remaining oil, water and gas to the 2 bbl/d economic limit — not a single point estimate.
Shows exponential, harmonic and hyperbolic fit options with the working confidence score and error metrics. If the fit does not explain history, the report holds the case in validation rather than promoting it to action economics.
A directional proxy — not a calibrated reservoir model — for whether water or gas is taking mobility and limiting oil flow. Used as a diagnostic pointer toward water-control vs. phase-interference hypotheses.
The report opens with the recommended stance, headline KPIs, uncertainty range and regime-shift context. Detailed pages underneath carry required field evidence, preliminary economics and a clear next-action owner.
Example screenshots on this page are intentionally rendered at low fidelity. The reports we prepare from your data are delivered in full detail.