4,196 STB/d
Find the missing barrels
The gap between actual production and technical potential, 8.3% of potential on the demo field, worth $87.31M a year before a single well is touched.
New 1,000 wells, full physics, in about a minute
Production Value Intelligence · v2.0
Find the barrels your field is missing.
PETROVALUE OPX measures the gap between what every well makes and what it could make, explains the engineering cause, and turns it into ranked, costed interventions that a named engineer approves — then checks whether the value was actually recovered.
Built-in 50-well demo field● Analysed
Actual46,436STB/d
Potential50,632STB/d
Gap4,196STB/d · 8.3%
$87.31M /yr
Opportunity value at $70/bbl less $10/bbl opex — before anyone touches a well
2,365 / 2,365planted faults named across 96 fields held out from tuning, with none of 1,475 healthy wells accused
11 / 11planted faults named on the demo field, with none of the other 39 wells flagged
68workspaces, from a buildup test to a year-by-year business plan
50 of 50wells anchored to their measured operating point before potential is computed
What it's worth to your asset
Barrels you already paid to find, finally produced.
Most producing fields run below what their wells, network and plant could deliver. PETROVALUE measures that gap well by well, prices it, and turns it into an approved, costed work programme. The figures below are what it finds on its built-in 50-well demo field.
$31.56M EMV
Put capital where it pays
A portfolio of 10 interventions for $1.17M of CAPEX, solved exactly against the capital budget and held inside the plant headroom and the rig days. On this field a value-density ranking reaches the same portfolio — and the planner says so on screen, rather than asking you to take the harder method on trust.
2,365 / 2,365
Know why wells underperform
On ninety-six fields held out from tuning it names all 2,365 planted faults and accuses none of 1,475 healthy wells. Every lost barrel is attributed to its causes, so the waterfall adds up to the measured loss.
70 s
Review the whole field, not a sample
A thousand wells and 730,000 daily records, with a nodal solve for every well and a gas-lift plan that respects the plant, in about seventy seconds on a laptop. The review that used to be a quarterly project runs whenever the data changes.
$0 until proven
Count only value that is real
Verified Value Recovered stays at zero until an executed job shows a sustained uplift. Outcomes feed back into success probabilities, so the next ranking learns from your field.
100% on-premise by default
Keep your data in-house
Runs offline on Windows, with no cloud upload and no data leaving your machines. Add SQL Server when a whole team needs to share one record. The one optional exception is the AI Agents workspace, which needs an internet connection and your own cloud account.
Opportunity calculator
What could your gap be worth?
Enter your field's numbers. The estimate uses the same arithmetic as the Command Center (gap × netback × 365 × uptime), which gives $87.31M a year for the demo field's 8.3% gap. Your real gap comes from your own data.
From signal to verified value
One chain, from a missing barrel to money in the ledger.
Each step feeds the next, and every figure carries the evidence that produced it. The only number the product counts as success is the last one.
Identify
Anchor each well's model to its measured operating point, then compute technical potential against reservoir, well, network and facility limits.
Diagnose
Name the most likely cause per well, with its confidence over competing hypotheses and the measurement that would confirm it.
Quantify
Share the loss across every contributing cause so the waterfall reconciles to the measured gap.
Rank
Turn diagnoses into actions with a success probability, a cost and a required approver; solve for the portfolio that fits the capital budget, the plant headroom and the rig days.
Decide
NPV, EMV, IRR and payout under your fiscal terms, with P90/P10 risk and low- and high-price scenarios.
Verify
Count value only when post-job uplift is sustained. Outcomes update success probabilities for the next ranking.
Built for whole fields
1,000 wells.
About a minute.
PETROVALUE analyses every well in parallel across all of the machine's cores. For each well it anchors a model to the measured rate, solves inflow against outflow, finds the binding constraint, diagnoses the loss, prices the opportunity and ranks the fix.
- Wells in one run
- 1,000
- Daily records analysed
- 730,000
- Full pipeline, measured
- 70 s
- Nodal solves per run
- 1 per well
Measured 24 September 2026 on an Intel Core i7-1165G7 laptop (4 cores, 32 GB RAM): three runs of 69.9–72.6 s on the shipping build. The same harness on the same laptop ran in 50 s a day earlier, and re-running that older build today gives 61–67 s — so most of the difference is the machine, not the software, and this figure is the shape of the number rather than a guarantee. The run is the whole pipeline — data quality, surveillance, a nodal solve and technical potential for every well, diagnosis, loss attribution, prediction and a field-wide gas-lift allocation that returns a plan inside the plant’s limits — on 1,000 wells carrying two years of daily data, with processing capacity sized for the field. Your figure depends on your hardware and your data; ask us and we will measure it.
Inside the application
A control room for production engineers.
Every screen below is the real application running the built-in demo field. Choose a workspace to look closer.
Command Center
OverviewEverything in the box
68 workspaces, one set of calculations.
Every workspace reads the same analysis run, so a number in the Command Center, a diagnosis in Well Explorer and a line in the Field Report always agree. Here is all of it.
01 Project
- Welcome Every capability of the product, and the ones open to your licence.
- Projects Keeps data, scenario, facility limits and register together; results are recomputed on open so none go stale.
- Settings Units, time axis, theme, engineering and fiscal defaults, idle lock.
- Users & Security Accounts, four roles, lockout and the audit trail.
- Licence What this installation is licensed to do, until when, and how to install a new licence.
02 Overview
- Process Overview The field as a process diagram, with each well coloured by its diagnosis.
- Command Center Actual against potential, the gap and what it is worth, where the barrels go, priority wells.
- Morning Brief What changed since the data directory was last opened. Nothing in it approves or sends a command.
- AI Copilot Plain-language or voice questions, answered only by registered calculations.
- AI Agents Optional AI agents that plan an analysis and call the product's own calculations. They need an internet connection and your own cloud account, send your question and summaries of results (never raw production records) to a cloud model, change nothing, and do nothing until an administrator sets them up. Available where your licence includes them.
- AI Model Runner Run your own ONNX models locally on field data.
03 Data
- Data & QC Import CSV, Excel, ECLIPSE decks or a database; column mapping and a QC score that gates the run.
- Parameters Catalogue Every input the application reads, the headings it accepts, its unit and default, and what each well holds.
- Surveillance Field trends, deferred production against each well's baseline, anomaly detection.
- Exceptions Moves past the surveillance limit on the data loaded now.
- Well Explorer One well's history, state, diagnosis, potential and actions.
- Digital Twin Measured against modelled behaviour; persistent deviations raise calibration candidates for review.
- Hydrocarbon Accounting Wellhead to export meter: shrinkage, own use, flare, unaccounted volume, gas balance.
- Back Allocation Oil, gas and water divided between wells and reservoirs, on every basis the data supports.
- Reservoir Health Pressure, bubble point, voidage, water, gas, offtake and surveillance, scored together and read with their coverage.
- Well Trajectories Every survey in one 3D scene, with Petrel export.
04 Engineering
- PVT Dry gas, wet gas and black oil with a choice of published correlations, then the condensate study: dew point and retrograde liquid dropout from an equation of state.
- Well Test Analysis Buildup and drawdown interpretation — the Horner line and the log-log derivative, permeability, skin and what that skin costs in drawdown.
- Gas Well Testing Multi-rate deliverability: the back-pressure curve, the rate at a stated drawdown and the non-Darcy coefficient.
- Nodal Analysis IPR against VLP with both roots found, pressure traverse, what-if choke, gas lift and wellhead pressure.
- Artificial Lift Natural flow, gas lift and ESP screened; economic optimum shown next to the technical one.
- Well Diagnostics Skin split into geometry, deviation and damage; flow efficiency; field benchmark.
- Water Breakthrough Chan and Y-function diagnostics: coning or channelling, with critical rate.
- Integrity & Flow Assurance Sand production review and hydrate screening along the line.
- Well Integrity Barrier envelopes and annulus pressures: which annulus is trapped, which is being fed, and which zone pairs are not proven apart. Says so when no records have been imported rather than scoring a well on invented ones.
- Log Digitization Read a curve off a scanned or photographed log and use it as a well log, calibrated by pointing at the image — and labelled as read off a picture rather than measured.
- Well Log Interpretation The curves, what they read as, and the contacts they identify: net pay over the logged interval, the zones, and the original contacts against what the logs show today.
- Formation Pressure Pretest pressures against depth: one gradient per fluid, the contacts where two gradients cross, the free water level and the transition zone.
- Completion Review Which perforated intervals are worth shutting off and which unperforated pay is worth adding, with pay, perforations and the fluid contact on one depth axis.
- Recompletion & ICV Which zone to open next, crossflow between zones, valve settings.
- Decline Analysis Arps, Duong or stretched exponential, forecast to the economic limit.
- Declinomics Engine Every well fitted in one pass, with drifting wells flagged for review.
- Type Curves Fetkovich, Blasingame and Agarwal-Gardner; flow regime and Arps readiness.
- Material Balance Flowing MB, Havlena-Odeh, drive indices, contact movement and a one-tank check.
- Gas & Aquifer p/z for gas reservoirs, and three aquifer influx models compared.
- Multi-Tank Balance Connected compartments balanced together: volumes, the transmissibility between them, and what each alone would claim.
- Technical Potential Reservoir, well, network and facility limits, and the one that binds.
- Reserves Outlook Empirical recovery factors against a fitted lifecycle profile.
- Facilities Plant capacities and utilisation; pro-rata against value-ranked allocation.
- Production System Every well solved against one shared network and separator.
- Integrated Production Model One branch per reservoir, naming the branch that constrains the system. A snapshot at today's reservoir pressures, not yet stepped through time.
05 Intelligence
- Loss Attribution The gap shared across weighted causes; the waterfall reconciles to the measured loss.
- Diagnosis Most likely cause per well, a confidence from competing hypotheses, the confirming test.
- Predictive Trend forecast with an 80% interval, early warnings and the value of acting early.
- Field Optimiser Gas lift and plant capacity allocated for maximum output, several periods ahead.
- Reservoir Optimization Stimulation, recompletion, drawdown and lift ranked by after-tax value.
06 Decision
- Economics NPV, EMV, IRR, payout, tornado sensitivity, P90/P10 and fiscal terms by terrain.
- Recommendations Ranked actions with success probability, cost, approver and a job plan.
- Prescriptive Planner The portfolio solved against the CAPEX budget, kept inside plant headroom and rig days, with the binding constraint named.
- Business Plan Production and cash year by year: the field’s own decline, the optimiser’s settings and the chosen interventions, within plant capacity and under the fiscal regime.
- Portfolio Several fields as one business: consolidated cash, capital allocation, risk.
- Performance & Priorities KPIs against targets and a balanced scorecard.
- Opportunity Register From identified to verified, with a named approver at each step.
- Scenarios The whole pipeline rerun at low price, high price and under cost pressure.
- Compare Wells or reservoirs overlaid: history, best opportunity, remaining reserves.
- Learning Verified outcomes update the success probability of each kind of job.
07 Governance, reports & help
- Evidence & Lineage Run id, data snapshot, scenario, model versions and evidence mix for every number.
- Model Governance Every kept run, decision and calibration, traced to the data and models behind it.
- API Access Published results for Power BI, Spotfire and other systems, read with a personal access token. Optional: a separate installer option that serves nothing until an administrator configures it, and only results someone explicitly publishes are readable. Available where your licence includes it.
- Field Report The management report in PDF, HTML, Word, Excel or PowerPoint.
- Well Report Every assessment of one well, saying which parts could not be produced and why.
- Export Center Every format the application writes, including Petrel deviation surveys.
- Help & Tutorials User and technical manuals, one click from anywhere.
Engineering depth
Published correlations, implemented properly — not placeholders.
Some decisions look small on paper and decide whether an engineer can trust the answer. These are enforced in code and asserted by the test suite.
Models are anchored to measurement first
A generic model routinely predicts less than a well is measurably making, so the gap turns negative and the opportunity vanishes. Anchoring fits productivity index and tubing friction to today's operating point — on the demo field, all 50 wells reproduce their measured operating point.
Loss is shared across causes
A well losing barrels to both water and a pinched choke is not recorded as water alone. Weighted attribution makes the loss waterfall sum to the measured loss.
Portfolio selection is solved, not ranked
Ranking by value density can't see that skipping one large job frees budget for three smaller ones worth more together, and it cannot weigh a cheap fix against the better one it would rule out on the same well. The planner solves over the capital budget instead, with plant headroom and rig days enforced on every candidate, then reports what the comparison found — on the demo field, that the ranking arrives at the same portfolio. It also says where its own guarantee stops: with two limits tight at once, the answer is the best plan the search reaches, not a proven optimum.
Failure is not free
A failed workover still costs its CAPEX and the production deferred during downtime, and incremental barrels decline over the evaluation horizon.
Numbers that can't be trusted say so
IRR returns nothing rather than an absurd annualised rate. Material balance refuses a volume its pressure record cannot support. When two methods disagree, the page says so rather than picking one.
| Area | What is implemented |
|---|---|
| PVT | Standing (Rs, Bo), Beggs–Robinson viscosity, z-factor — evaluated at each traverse segment's local pressure. Gas-condensate dew point and liquid dropout from an equation of state. |
| Inflow | Productivity index, Vogel, and a composite form across the bubble point; skin through Darcy's radial form, split into geometry, deviation and remaining damage. |
| Outflow | Beggs & Brill with the real flow-pattern map, holdup and inclination correction; Hagedorn & Brown; Duns & Ros — over a segmented traverse. |
| Nodal & lift | Both roots of IPR = VLP; what-if choke, gas-lift and wellhead pressure; gas-lift and ESP screening with the economic optimum reported separately from the technical one; liquid-loading check. |
| Decline & type curves | Arps (b bounded 0–1), Duong and stretched exponential down to the economic limit; field-wide automated sweep; Fetkovich, Blasingame and Agarwal-Gardner diagnostics. |
| Reservoir | Havlena-Odeh material balance with drive indices and contact movement; p/z for gas; three aquifer influx models; reserves outlook against empirical recovery factors. |
| Water | Chan diagnostic and Y-function to separate coning from channelling, with critical rate. |
| Integrity & completions | Sand production review that refuses a default rock strength; hydrate and flow-assurance screening along the line; zone-by-zone recompletion and ICV settings with crossflow between zones. |
| Network & facilities | Every well solved against one shared gathering network and separator; integrated model with one branch per reservoir that names the binding branch; pro-rata versus value-ranked allocation. |
| Economics | NPV, EMV, IRR, payout, price sensitivity and P90/P10 risk; fiscal regimes by terrain, including the Nigerian regime; multi-scenario reruns of the whole pipeline. |
AI Copilot
An assistant that cannot make up a number.
Ask about the field in plain language — or by voice. The copilot routes your question to one of the registered engineering calculations, reads what it returned and explains it. Every figure traces to a tool call and carries an evidence label.
- intent
- permission
- context retrieval
- deterministic tool
- validation
- explanation
- evidence
- Names the calculation that produced every answer, and says so when it has no result to read.
- Bring your own ONNX model and run it locally — no model ships with the product, and no claim is made about its output.
- Will not invent a rate, pressure, economic figure or reserve.
- Refuses to approve an intervention or change a well setting. Those need a named engineer.
PETROVALUE Copilot50 wells loaded
You
What is wrong with W16?
Copilot
W16 — Wellbore restriction (high confidence, critical severity).
Production loss is 860 STB/d. The signal persisted on 21 of the days examined, which separates it from a one-day artefact.
Recommended next step: review tubing pressure drop, run a gauge or caliper, and check integrity indicators. The test that would confirm or refute this: a gauge run or caliper log locating the restriction.
This is an AI interpretation of measured signals, not a confirmed root cause.
AI Interpretation
Computed by: Automated diagnosis
You
Approve the workover on W16.
Copilot
I can't approve or execute interventions. Approval requires a signed-in engineer with the Approve permission, and is recorded against that person in the audit trail.
ObservedCalculatedEstimatedAssumedAI Interpretation
Governance & security
The software recommends. A named engineer approves.
These rules are enforced in code and asserted by the test suite — not written in a policy document and hoped for.
Scope
Decision support only
PETROVALUE never issues live well-control commands. The what-if simulator changes nothing measured and writes nowhere.
Models
No silent recalibration
The digital twin raises a calibration candidate for review. Calibration returns a proposal, never a mutation.
Approval
Humans sign off
Approval, execution authorisation and verification each refuse an automated actor, and are recorded against the signed-in person — never a typed name.
Lineage
Every number traceable
Evidence & Lineage shows the data snapshot, scenario, model versions, run identifier and the mix of observed, calculated and assumed evidence.
Freshness
No stale results
Results are recomputed when a project opens, so a number cannot outlive its assumptions. Changing the scenario marks the run stale.
Access
Accounts, roles, audit
Password policy, lockout, idle lock; Viewer, Engineer, Approver and Administrator roles; append-only audit trail; no default credentials.
Validation
Scored on fields held out from tuning.
Every field here is generated forward from physical causes — nodal solved per well, per day — with faults planted inside it at random onsets and severities, and healthy wells carrying harmless disturbances. Diagnosis has to find them through real mechanisms. The score that counts is on 96 fields that were held out when the engine was tuned.
Faults named, 96 held-out fields2,365 of 2,365
Healthy wells accused there0 of 1,475
Planted faults named on the demo field11 of 11
Other demo wells flagged0 of 39
Packaged self-test before any release shipsPassed
2,365/2,365faults named on held-out fields · 0 of 1,475 healthy wells accused
Planted fault — namedNot flagged
Choke position separates backpressure from a pinched choke; productivity-index decline separates skin damage from depletion; rising drawdown with flat wellhead pressure marks lift degradation. On the demo field every planted fault is named exactly, and no well without one is flagged.
Built for the control room
Four themes, from the night shift to the boardroom projector.
Switch with one click in the header; every chart redraws in the new palette. The same Command Center, the same run, four ways.
The palette is not applied to one screen. It carries into every workspace — see eleven of them, in all four themes.
Screenshot gallery
Eleven workspaces, four themes, one run.
Charts, tables, badges, the process diagram and the alarm log all take their colours from the active palette. These follow the work in order — the field, then the well, the reservoir, the cause, the money and the report that leaves the building. The readings are identical in every row, so the only thing changing is the colour. Click any of them to enlarge.
Control room near-black, high contrast — the default
Night warm amber for a dark control room
Dark slate panels for long desk sessions
Light projectors, print and bright offices
Deployment
A native Windows application, deployed your way.
PETROVALUE OPX is a native Windows application. It installs like any enterprise desktop application, runs without an internet connection by default, and keeps your data on machines you control.
Install & run
- Platform
- Windows 10 and 11, 64-bit; nothing else to install
- Install
- MSI installer, or a portable zip that runs without installation
- Charts
- Pan, zoom, hover read-outs, span selection, log and twin axes; 3D well trajectories
- Reports
- PDF, Word, PowerPoint, Excel and HTML
- Offline AI
- Voice input with on-device speech; your own ONNX models run locally
Data & security
- Database
- Built-in project store by default; SQL Server with one configuration line for teams that share one record
- Sign-in
- Local accounts, password policy, lockout, idle lock
- Roles
- Viewer, Engineer, Approver, Administrator
- Audit
- Append-only trail of sign-ins, analyses and approvals, each against a named person
- Defaults
- No default credentials — the first start asks you to create the administrator
ECLIPSE decks
Import .DATA decks — WELSPECS, COMPDAT, PVT tables — with what was parsed reported back.
LAS well logs
Drop a LAS file onto the page to view it as tracks alongside the well's history.
Petrel surveys
Export directional surveys as a deviation table Petrel reads directly.
Your own data
An input template lists every column read; QC reports each mapping and remedy, and gates the run.
# verify the packaged build before you trust it > PetroValue.exe --selftest --out report.txt # headless field report, no display needed > PetroValue.exe --report --data field.csv # keep the application store on a shared drive > PetroValue.exe --data-dir D:\pv-store
Why teams switch
From a spreadsheet per well to one answer per field.
| The usual way | With PETROVALUE | |
|---|---|---|
| Coverage | A sample of wells reviewed each quarter | Every well, every run: 1,000 wells and 730,000 daily records in about a minute |
| Models | Generic correlations that disagree with the meter | Each well anchored to its measured operating point first |
| Root cause | The first plausible explanation | Competing causes scored, and the test that would confirm each one |
| Priorities | Ranked by gut feel or value density | A portfolio solved against the budget, inside plant headroom and rig days |
| Economics | A separate model, rebuilt for every job | NPV, EMV, IRR and fiscal terms on the same run |
| AI | An assistant that writes an answer, with no way to check where a number came from | A copilot that only reports what a registered calculation returned, labelled with its evidence |
| Proof | Value claimed when the job is done | Value counted only after a sustained, verified uplift |
| Data | Uploaded to someone else's cloud | Stays on your machines, offline by default |
Your field has missing barrels. Let's find them.
Walk the demo field with us, then load a sample of your own production data. Your data stays on your machines.
Pricing
Licensed by team, not by feature.
Every plan runs the same engineering calculations. Plans differ in who uses the software and how it is deployed, not in which calculations you get. Annual licences in US dollars; Enterprise is priced to your assets and teams. Would you rather not run it yourself? We evaluate your field for you, per well.
Engineer
For one production or reservoir engineer on their own workstation.
$50,000 per user / year
- One named user
- Every engineering, intelligence and decision workspace
- AI Copilot, with voice input and local ONNX models
- Built-in project store, fully offline
- ECLIPSE deck and LAS log import, Petrel survey export
- PDF, Word, PowerPoint, Excel and HTML reports
Asset Team Recommended
For an asset team that finds, approves and verifies interventions together.
$100,000 per year, up to 3 users
Everything in Engineer, plus:
- Up to 3 named users
- Viewer, Engineer, Approver and Administrator roles
- Opportunity register with named approval and verification
- Append-only audit trail recorded against each signed-in person
- Shared SQL Server database
- Onboarding session with a sample of your own data
Enterprise
For operators running several assets, or building PETROVALUE into their own workflows.
Contact us priced to your assets and teams
Everything in Asset Team, plus:
- Licensing across several assets and teams
- Portfolio workspace: several fields consolidated as one business
- Headless reports from the command line for scheduled runs
- MSI deployment and a shared application store
- Training for engineers and approvers
Or have us do it
Field and well evaluation, run by our engineers
No licence, no installation, no learning curve. Send us your production and static data and we run PETROVALUE over your field: every well anchored to its measured rate, the gap quantified, the causes diagnosed, the interventions ranked and costed under your fiscal terms.
- A report per well and one for the field, with the evidence behind every number
- Ranked, costed opportunities with success probabilities and required approvals
- A walkthrough of the findings with your engineers
- Your data is handled on our machines and returned or destroyed on request
$10,000 per well
Priced per well evaluated. Tell us how many wells and we will confirm the scope before any work starts.
Request an evaluation
Every plan includes
- The full set of engineering calculations
- The 50-well demo field
- Packaged self-test for every build
- User and technical manuals, one click from inside the application
- Your data stays on your machines by default
Questions
What engineers ask first.
Does PETROVALUE control wells or change setpoints?
No. It is decision support. It does not issue live well-control commands, and the what-if simulator writes nowhere. Approval and execution of any intervention require a named engineer with the right permission.
Where does the AI come in — and can it hallucinate figures?
The copilot is an interface to the engineering calculations: it can only report what a registered calculation computed, labelled with its evidence type. The learning layer that does adapt scores executed interventions against their predictions and re-ranks future recommendations from your own field's results.
What data do I need to start?
Daily production per well (oil, water, gas, pressures, choke) plus static tables for wells and reservoirs. Download the input template from the Data & QC workspace — it shows every column the application reads. Quality checks score the import and stop the run before economics if the data can't support it.
Does it need an internet connection or the cloud?
No, not by default. PETROVALUE runs offline on Windows. Voice input uses offline speech, and ONNX models run locally. It can optionally point at a SQL Server database for shared deployments. The one exception is the optional AI Agents workspace: it needs an internet connection and your own cloud account, and it sends your question and summaries of the analysis results — never the raw production records — to a cloud model. It does nothing until an administrator sets it up.
Can it read PROSPER or GAP files?
Not today. Those are proprietary formats without a public specification to verify a parser against. ECLIPSE .DATA decks and LAS logs are supported.
Which fiscal terms are supported?
Economics applies fiscal regimes by terrain — including the Nigerian regime — and compares regime families. Price, operating cost, discount rate and uptime are held in an editable scenario.
How is PETROVALUE priced?
By annual licence, in US dollars. Engineer is $50,000 per user per year. Asset Team is $100,000 per year for up to 3 users, with roles, the shared SQL Server register and an onboarding session. Enterprise, for several assets and teams, is priced to your deployment, so contact us. If you would rather not run the software yourself, our engineers evaluate your field for $10,000 per well. Every plan includes the full set of engineering calculations, so you never pay extra to unlock a calculation.
How do I try it?
Request a demo below. Every installation ships with a physically generated 50-well demo field, so you can explore every workspace before loading your own data.
Request a demo
See your own gap.
Tell us about your field. We'll walk through the demo field with your team, then help you load a sample of your own production data.
A 45-minute walkthrough, tailored to your assets
Evaluation installer with the full demo field
Your data stays on your machines — nothing is uploaded unless you turn on an optional cloud feature
In a hurry? Message us on WhatsApp — +234 708 745 4519