Wellbore Genius
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Display units. Picks below are display-only — the G-function, √t and step-rate fits always run in field units. Every card shows the metric equivalent underneath.
Pressure
Temperature
Density
Viscosity
Confidence in this interpretation
Four independent dimensions — none is inferred from another. Overall: Limited by numerical convergence: not established.
Input completeness
Moderate
5 of 6 required inputs supplied. Missing: True vertical depth.
Model uncertainty
Moderate
2 physical assumptions stood in for measured data.
Numerical convergence
Not established
Solver did not report a convergence status.
Calibration quality
Not established
No field measurements have been matched against this run.

Calibration is not established yet. Enter field readings — measured ISIP, closure pressure, G at closure — and this rating updates from the matches.

Synthesized trace — illustrative only, not a measured DFIT

Every pick, closure pressure, slope and uncertainty band below is computed from the schedule you typed above, not from field data. The fits look near-perfect because the trace is noiseless by construction, so the error bars describe the algorithm, not your well. Upload or paste a real trace before quoting any of these numbers.

DFIT WorkbenchMethod

ISIP back-extrapolation, G-function closure, √t after-closure linear flow, and step-rate analysis on the synthesized injection trace. Edit the inputs to drive every plot in real-time.

Injection schedule
Drives the synthesized pressure trace.
Diagnostic picks
Auto-derived from the current trace.
ISIP [psi]
7,120 psi
≡ 49.09 MPa
90% CI [7120, 7120] · σ 0.0
R² 1.000
Shut-in time [min]
4.00
P @ shutin 7,120 psi (49.09 MPa)
Closure Pc [psi]
6,935 psi
≡ 47.81 MPa
90% CI [6935, 6935] · σ 0.0
G* 1.01
Pump time tp [min]
4.00
tangent 0 psi/G (0.00 MPa/G)

CIs at 90% — ISIP from analytic OLS SE; Pc from 200-sample residual bootstrap.

Test conditions
Recorded conditions the DFIT was measured under. Displayed in your picked units with the metric equivalent — no diagnostic pick below is computed from them. The injected-fluid viscosity is what a run picks up when you switch it over to your DFIT numbers.
210.0 °F≡ 98.9 °C
8.40 ppg≡ 1,007 kg/m³
1.0 cP≡ 1.0 mPa·s
Client deliverable (Excel)
Illustrative trace
One workbook: cover and provenance, the DFIT picks, the stage-by-stage frac plan they feed, the full design basis, and the pressure trace. Every value is a live number, so the client can recalculate.
Stages
50
Clusters
300
Max surface pressure
7,760 psi
Proppant
20,000 klb
Edit the frac design

The trace is synthesized from typed inputs, so the workbook labels every pick illustrative on the cover and in the results sheet.

Measured DFIT trace
Upload a recorded pressure/rate CSV to drive every plot below with real shut-in data. Auto-detects columns named like t [min], pressure [psi], rate [bpm]. Units in brackets ([s], [kPa], [MPa], [bar], [m3/min], [gpm]) convert on the fly.
Driving plots: synthesized
Sampling cadence diagnostics
Verifies the measured trace is monotonic, has no duplicate timestamps, and samples evenly enough for stable G-function derivatives. Runs on the raw CSV trace before preprocessing.
Idle (synthesized trace)

Load a measured DFIT CSV to run cadence checks.

Preprocessing
Condition the measured trace before ISIP, G-function, and √t picks. Smoothing reduces dP/dG noise; outlier rejection (Hampel filter) clips sensor spikes; baseline correction subtracts a constant or linear pre-shutin drift.
Idle (synthesized trace)
Closure picking (G·dP/dG)
Tune the algorithm and tangent window used to extract G* and Pc from the G-function diagnostic.
algo: tangent-departure

Tangent slope (median of G·dP/dG ÷ G inside [0.30, 1.00]) = 0 psi/G (0.00 MPa/G). Departure threshold and min-closure G only apply where the algorithm uses them.

Plots
Pressure trace, G-function diagnostic, and √Δt after-closure plot.
ISIP 7,120 psiPc 6,935 psiPressure [psi] · Rate [bpm]time [min]
Stage-by-stage DFIT
Auto-detects every pump-then-shutin segment in the active trace and runs the same ISIP / G-function / closure pipeline on each. Click a stage to drill in; compare ISIP, Pc and net pressure across stages.
1 stage detected
StageAvg rate [bpm]Pump [min]Falloff [min]ISIP [psi]Pc [psi]G*Net P [psi]
Inj-1
schedule
5.003.0030.007,120 psi (49.09 MPa)6,966 psi (48.03 MPa)1.01154 psi (1.06 MPa)
Selected: Inj-1
Slice 16…680 (665 samples) · shut-in @ 4.00 min
ISIP 7,120 psiPc 6,966 psiPressure [psi] · Rate [bpm]time [min]P [psi] and G·dP/dG vs GPc 6,966 psi @ G* 1.01
Inj-1ISIP [psi]Pc [psi]Net P [psi, above floor]
Step-Rate Test
Edit stabilized rate / pressure pairs. Two-line regression finds the formation parting rate and pressure.
Parting rate [bpm]
4.85
90% CI [5, 5] · σ 0.0
4.9 bpm equivalent
Parting pressure [psi]
7,048 psi
≡ 48.59 MPa
90% CI [7040, 7053] · σ 3.9
Matrix slope [psi/bpm]
220 psi/bpm
≡ 1.52 MPa/bpm
Fracture slope [psi/bpm]
46 psi/bpm
≡ 0.31 MPa/bpm
Rate [bpm]Stabilized P [psi]
Stabilized P [psi] vs Rate [bpm]
Parting at 4.85 bpm / 7,048 psi (48.59 MPa)
Sand, water and trucks for this job
Build a daily calendar on the frac schedule and its real sand, water and truck counts show up here and on every run you keep.
My saved fluid-injection test runs
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Keep the schedule, closure-pick settings and step-rate table for this test. Signed in, each run stays on your account, so logging out does not lose it. A measured file is not stored — reload the file and open the run to get its settings back.

Want the full list with dates and units side by side? Open my saved runs. Need a quick conversion instead? Open the unit converter.