SAFA measures pipe friction, perforation friction, and cluster-level flow distribution in real time — giving your completions team actionable data while the stage is still pumping. Surface-based. Non-invasive. Every stage.
Surface treating pressure tells you something is happening. SAFA tells you what and where. Using high-frequency acoustic signals generated during controlled rate changes, SAFA isolates and quantifies five subsurface parameters — in real time, without downhole hardware.
When clusters drop out intra-stage, stimulation volume concentrates in dominant fractures. You spend the same money but stimulate less rock.
The percentage of perforations in a stage actively taking fluid. SAFA quantifies perforation efficiency continuously — at every rate event, intra-stage — so your team can act before the stage ends.
Why it matters: Stages receiving intra-stage intervention show 33% less perforation efficiency degradation. Without real-time measurement, efficiency losses accumulate unnoticed across every stage.
Conventional step-down tests measure perforation friction once at the start or end of a stage. SAFA measures it continuously while pumping.
Uneven cluster flow means some fractures receive all the fluid while others starve — leading to variable drainage, accelerated depletion near dominant clusters, and stranded reserves.
A 0-to-1 metric describing how evenly fluid distributes across all clusters in a stage. A UI of 1.0 means perfectly uniform flow. Published R² = 0.92 correlation with 12-month cumulative production (SPE-230647).
Why it matters: Every 0.1-point UI increase adds approximately 2.5% first-year production and ~$300K in NPV per well. In the Permian, a 0.10-point UI increase correlates with 6–10% more production. In the Williston, 7–12%.
Achieving comparable flow distribution data typically requires $700K+ in permanent downhole fiber — limiting measurement to a handful of flagship wells. SAFA delivers UI from the surface, on every stage, every well.
Pipe friction is the single largest component of treating pressure, yet the industry routinely estimates it from fluid correlations. A 200–400 psi misallocation propagates through every downstream calculation.
The frictional pressure loss along the wellbore from surface to perforations. SAFA separates pipe friction from perforation friction directly — eliminating the guesswork that corrupts perf efficiency, UI, and flow area calculations.
Why it matters: Incorrect pipe friction means incorrect perforation friction, incorrect efficiency numbers, and incorrect decisions. It is the foundation of every other completions KPI.
No other surface-based diagnostic system measures pipe friction independently. Conventional methods assume it from fluid correlations that vary with temperature, proppant loading, and friction reducer concentration.
Perforation friction changes throughout every stage as perforations erode and proppant scours entry points. Measuring it once means designing the next stage on stale data.
The pressure drop across the perforations themselves. By measuring perforation friction independently and continuously, SAFA reveals how much resistance the rock face and perforation geometry impose on fluid entry — a value that evolves throughout every stage.
Why it matters: Accurate, real-time perforation friction is the required input to every flow distribution and cluster efficiency calculation. Without it, UI and perf efficiency numbers are estimates, not measurements.
Surface pressure analytics blend pipe friction and perforation friction into a single number. Fiber optics measures temperature and strain — not friction directly.
Excessive perforation erosion or a leaking plug is invisible to treating pressure. The first indication is often a production shortfall discovered months later.
The inferred cross-sectional flow area of open perforations, calculated from measured perforation friction. Abnormally high flow area flags excessive erosion or plug failure intra-stage — problems that treating pressure alone cannot detect.
Why it matters: A single undetected plug leak can cost $150K or more per occurrence in wasted fluid and remediation. Early detection enables intra-stage intervention while there is still time to act.
Downhole imaging can visualize erosion geometry after the frac. SAFA detects abnormal flow area changes in real time, during pumping.
High-frequency pressure transducers mount directly on the surface injection lines. A compact data acquisition unit connects to your frac data van. No downhole tools, no fiber, no offset well, no additional NPT. Installation takes minutes and works with any pumping company.
During each stage, controlled rate changes generate high-frequency pressure signals that SAFA analyzes to isolate pipe friction from perforation friction independently. The system triggers automatically on every rate change — planned or unplanned — delivering results within seconds.
Within seconds of each rate event, SAFA streams perforation efficiency, Uniformity Index, and flow area to a live dashboard. Predefined decision logic flags when UI drops below threshold, when perforation efficiency degrades, or when flow area indicates a plug leak — enabling immediate intervention.
| Capability | SAFA | Fiber Optics | Step-Down Test | Downhole Imaging |
|---|---|---|---|---|
| Surface-based (no downhole hardware) | Yes | No — requires permanent cemented fiber | Yes | No — requires downhole tool run |
| Real-time, intra-stage | Yes | Yes* | No — beginning or end of stage only | No — post-frac only |
| Cluster-level resolution | Yes | Yes | No — assumes friction values | Yes |
| Measures pipe and perf friction independently | Yes | No | No — cannot decouple | No — measures geometry, not friction |
| Non-invasive (zero NPT) | Yes | No — installation adds days | Yes | No — requires wireline trip |
| Works with any pumper | Yes | No — tied to specific providers | Yes | Yes |
| Scalable to every well | Yes | No — $700K-$1M per well | Moderate | Moderate — per-well imaging cost |
| Production correlation (published R²) | 0.92 | Reference standard | N/A | Measures erosion, not flow distribution |
| Actionable intra-stage | Yes | Yes | No | No — post-treatment diagnostic |
| Cost | ~1/10th of fiber | $700K-$1M per well | Low | $50K-$150K per well |
| Real-time flow area / plug leak detection | Yes | Post-frac only | No | No |
* Fiber optics delivers intra-stage data only with permanently cemented installations, which are not economically scalable across a development program.
From Passive Monitoring to Active Control
SAFA doesn't just measure — it drives decisions. Every metric connects to a specific intervention that improves well economics.
Measurement: Perforation efficiency drops below threshold mid-stage.
Action: Completions team adjusts pump rate or re-perforates. Clusters that would have remained closed are opened during the stage — not discovered post-job.
Measurement: Uniformity Index shows uneven flow distribution across clusters.
Action: Rate adjustments or diverter deployment redistribute fluid to underperforming clusters. Result: 0.42 → 0.74 UI improvement documented in field deployments.
Measurement: Flow area exceeds expected value, indicating fluid loss to a previous stage.
Action: Crew stops pumping, reseats or replaces the plug. Prevents wasted fluid and unplanned screen-outs — saving $50K-$100K per incident.
By acting on live perforation efficiency and UI data during execution, completions teams achieved measurable improvements in cluster flow distribution, reduced fluid waste, and identified equipment failures intra-stage.
See what SAFA reveals about your completions program. Our team will scope a pilot deployment tailored to your basin, well design, and operational workflow — with results on the first well.