Why non-productive time is the number that decides the drilling budget
Drilling a well is the largest discrete spend most upstream operators make, and almost all of it is rate-driven: the rig costs the same per day whether it is making hole or sitting idle. That makes non-productive time - the hours lost to equipment failures, waiting on weather, stuck pipe, well-control events and downtime - the single biggest controllable variable in well cost. Yet on many wells the true picture of where time and money went is only assembled after the well is finished, from daily drilling reports, cost systems and the AFE that were never joined together while it mattered.
Good drilling and completion reporting closes that gap: it tracks depth, rate of penetration, NPT and cost against AFE while the well is being drilled, so the drilling team and the office see the same picture and act on it in time to change the outcome.
The metrics that belong on a drilling and completion dashboard
- Depth vs days - actual progress against plan, the classic drilling curve
- Rate of penetration (ROP) - by formation and section, against offset wells
- Non-productive time - hours and cost, classified by cause
- Cost vs AFE - actual and committed spend against the authorisation, by phase
- Tripping and connection times - the repetitive operations where small gains compound
- Mud, casing and cementing activity - the consumables and operations behind well integrity
Monitoring drilling events, equipment performance and risk
Most serious drilling problems announce themselves before they become expensive. A trend in torque and drag, a creeping increase in connection time, an equipment parameter drifting out of range - these are visible in the data well before they turn into stuck pipe or a failure on the critical path. A useful drilling dashboard surfaces these leading indicators in near real time so the drilling team can intervene while the problem is still cheap to fix.
Tracking cost against AFE and identifying delays early
The AFE is the budget the well was approved against, but it only controls cost if actual and committed spend are tracked against it continuously, phase by phase. A dashboard that shows cost-vs-AFE next to the depth curve and the NPT breakdown makes overspend explainable while there is still time to respond - and gives the office an early, evidence-based warning when a well is heading past its authorisation rather than a surprise at well completion.
Linking drilling performance to future well productivity
How a well is drilled and completed shapes how it will produce for years. Wellbore quality, completion design, cementing integrity and the way the reservoir section was drilled all carry forward into productivity. Reporting that preserves this link - connecting the drilling and completion record to subsequent well performance - turns each well into a lesson for the next, so the drilling programme improves rather than just repeats.
End-of-well review vs real-time drilling reporting
| Aspect | End-of-well review | Real-time drilling reporting |
|---|---|---|
| When problems are seen | After the well is finished | While the rig is still on the well |
| NPT analysis | Reconstructed from reports | Classified by cause as it happens |
| Cost control | Reconciled after the fact | Tracked against AFE phase by phase |
| Learning across wells | Lost between projects | Offset comparison built into the programme |
Drilling and completion reporting across operating contexts
Offshore rigs
Very high day rates make NPT extraordinarily expensive. Reporting that surfaces leading indicators of trouble in near real time pays for itself in a single avoided incident.
Land rigs
Multi-well campaigns where consistency and repeatability drive cost. Offset comparison and connection-time tracking turn small per-well gains into large programme savings.
Shale pads
Factory-style drilling of many similar wells. Standardised reporting across the pad exposes the best-performing sequences and rolls them out, well after well.
The Power BI architecture behind drilling and completion reporting
On a typical SolveBI deployment we land daily drilling reports, rig-sensor and WITSML data, cost-system actuals and the AFE into Microsoft Fabric, then expose a single well-delivery model through Power BI. The rig team sees the live depth, ROP and NPT view; the drilling office sees the cost-vs-AFE and offset-comparison view; management sees the programme-wide NPT and cost picture - all from one Power BI dataset that ties operations to spend.
Common mistakes in drilling and completion reporting
- Total NPT only. Without cause classification, recurring problems are never engineered out.
- Cost reconciled after the well. Tracking against AFE only matters if it happens while the rig is still drilling.
- Ignoring leading indicators. Torque, drag and connection-time trends warn of trouble before it gets expensive.
- No offset comparison. Without it, every well starts from scratch instead of from the last well's lessons.
- Drilling divorced from productivity. Losing the link to later well performance wastes the most valuable feedback there is.
From end-of-well surprises to in-well cost and NPT control.
Book a free 30-minute consultation with a Microsoft-certified SolveBI consultant. We'll map your daily drilling reports, rig-sensor and cost data, agree the right drilling metrics, and quote a phased Power BI deployment you can budget against.
