Wellbore Genius

Pad-scale reference audit

Every published reference stage solved through the same whole-pad kernel as /pad-parallel (stage-parallel/1.0.0), with the field inputs, the solver inputs, the model geometry and the measured values in one row. Deltas are only shown as accuracy where the model quantity and the measurement are the same physical thing.

Graded verification suite Compare your own well

Shadow cast by every cluster of the stage

One fracture stands in for the whole stage (historical behaviour): Δσ stays under 10 psi at 250 ft, an order below the field inference.

Field-calibrated physics

Solved with the constants fitted to HFTS-1 and MSEEL.

Fitted defaults

Tune the constants

Constants from a measured core

No saved core yet, so this page is solving with the constants fitted to the published HFTS-1 cores. Import and save your own core report and it will take their place here.

Import a core

Constants from a measured log and pressure test

No saved well log or DFIT yet, so this page is solving with the constants fitted to the published field data. Import a log and a shut-in pressure test and their permeability, closure stress and proppant reach take their place here.

Import a log or pressure test

Well path and rate history

No saved deviation survey or production history yet, so this page uses the published pad's own depth and spacing. Import a survey and its true vertical depth, inclination and azimuth set the closure stress and stage spacing solved here, while rate history is compared against the modelled propped reach.

Import a survey or rate history

Fluid model (black-oil PVT)

The pad-scale kernel solves with a single-phase fluid. These curves show where that assumption stops holding for this well's fluid, so a disagreement can be read rather than guessed.

Oil gravity (°API)

Gas gravity (air = 1)

Producing GOR (scf/STB)

Water cut (%)

Reservoir temp (°F)

Use my well's own data

Nothing imported yet measures a fluid property, so these curves come from the typed values above. Import a PVT lab report — plus a well log, a DFIT and a production history — and the oil and gas gravity, gas-oil ratio, bubble point, temperature and pressure will all come from your well instead.

Import my well data

Black-oil PVT curves at 210 °F

p_b 3,201 psia

Solution gas R_s (scf/STB) & B_o (rb/STB)

Gas z-factor & oil viscosity (cP)

Mixture density (ppg)

In-situ free gas (% of volume)

Standing R_s / B_o with Vasquez-Beggs undersaturated corrections, Dranchuk-Abou-Kassem z-factor and Lee-Gonzalez-Eakin gas viscosity. Below p_b the mixture density is a no-slip average: the true two-phase gradient needs a holdup model, so read it as an upper bound.

Compositional cross-check

Flash pressure

1,920 psia

Phase state

two-phase

Vapour (mol)

8.5 %

Vapour (mass)

2.8 %

Apparent GOR

101 scf/STB

Condensate yield

9,892.1 bbl/MMscf

Liquid gravity

77.3 °API

Vapour gravity

0.873

The two fluid models differ by -79%. Treat the black-oil gas figures as indicative and confirm with a measured PVT report.

Component	z	x (liquid)	y (vapour)	K
N2	0.0040	0.0022	0.0229	10.181
CO2	0.0120	0.0112	0.0207	1.850
C1	0.3400	0.2559	1.2476	4.875
C2	0.0750	0.0746	0.0792	1.061
C3	0.0550	0.0583	0.0194	0.333
iC4	0.0110	0.0119	0.0018	0.149
nC4	0.0260	0.0281	0.0032	0.115
iC5	0.0120	0.0130	0.0007	0.053
nC5	0.0140	0.0152	0.0007	0.044
C6	0.0210	0.0229	0.0004	0.018
C7+	0.4300	0.4698	0.0004	0.001

Wilson K-values with a Rachford-Rice solve — a screening split, not a converged fugacity balance. Source: Typical Wolfcamp B separator recombination.

Read the comparability column before the delta

HFTS-1 cores measure propped half-length while the kernel reports hydraulic half-length, so that pair is bracketed and flagged rather than scored. MSEEL DAS P50 half-length and the SRV height envelope are hydraulic quantities and compare directly.

HFTS-1 Midland Basin Wolfcamp core-through-frac

Per-stage propped half-length, fracture count, and vertical containment from HFTS-1 through-fracture cores. Use to validate propped extent and height-growth in bounded Wolfcamp stacks.

converged · 2 waves

worst like-for-like Δ +9.7%

max Δσ 8.0 psi

5 solved cases

Ciezobka, J. et al. (2018). Overview of Hydraulic Fracturing Test Site (HFTS-1) in the Permian Basin. URTeC-2937168.
Gale, J. F. W. et al. (2018). Natural fractures in the Wolfcamp Formation and their effect on hydraulic fracture propagation. URTeC-2902624.
Raterman, K. T. et al. (2019). Analysis of a drained rock volume: an eagle ford example. URTeC-2019-263-EG (methodology reference).
Values retrieved 2026-07-13.

stage-a

PKN

Field inputs (published)

Slurry pumped: 8500bbl
Stage rate: 82.0bpm
Proppant: 480,000lb
Clusters: 4–
Perfs per cluster: 6–
Pay thickness: 200ft
Barrier above: 0.90Mpsi
Barrier below: 0.60Mpsi

Solver inputs

Rate per cluster: 20.50bpm
Pump time: 103.7min
Young's modulus: 4,500,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft
Barrier contrast above (this stage): 234psi
Barrier contrast below (this stage): 156psi
Leak-off contrast (this stage): 0.66×

Model results

Hydraulic half-length: 1909ft
Fracture height: 170ft
Average width: 0.085in
Net pressure: 125psi
Stress shadow Δσ: 0.0psi
Rate derate: 1.000–
Fluid efficiency η: 0.308–
Fracture volume: 3680ft³
Leak-off volume: 8254ft³
Pumped volume: 11,934ft³
Propped half-length: 245ft
Propped / hydraulic: 0.128–
Proppant pack volume: 1116ft³

Quantity	Model	Measured	Δ	Comparability
Propped half-length	245 ft	240 ft	+2.0%	Propped tip set by pack volume; compared against core-recovered proppant extent, which is the same quantity.
Hydraulic extent	1909 ft	240 ft	(+696%)	Not comparable — Hydraulic extent against core propped extent — never an error bar. Read it as a ratio sanity check; the like-for-like propped comparison is the row above.
Height	170 ft	170 ft	+0.1%	Like-for-like

Measured field values

Propped half-length (core): 240ft
Height above+below perf: 170ft
Fractures per stage (core): 190–

stage-b

PKN

Field inputs (published)

Slurry pumped: 9100bbl
Stage rate: 85.0bpm
Proppant: 520,000lb
Clusters: 5–
Perfs per cluster: 6–
Pay thickness: 210ft
Barrier above: 0.85Mpsi
Barrier below: 0.55Mpsi

Solver inputs

Rate per cluster: 17.00bpm
Pump time: 107.1min
Young's modulus: 4,500,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft
Barrier contrast above (this stage): 128psi
Barrier contrast below (this stage): 83psi
Leak-off contrast (this stage): 1.40×

Model results

Hydraulic half-length: 805ft
Fracture height: 188ft
Average width: 0.064in
Net pressure: 86psi
Stress shadow Δσ: 5.9psi
Rate derate: 0.936–
Fluid efficiency η: 0.135–
Fracture volume: 1294ft³
Leak-off volume: 8272ft³
Pumped volume: 9566ft³
Propped half-length: 271ft
Propped / hydraulic: 0.336–
Proppant pack volume: 905ft³

Quantity	Model	Measured	Δ	Comparability
Propped half-length	271 ft	265 ft	+2.2%	Propped tip set by pack volume; compared against core-recovered proppant extent, which is the same quantity.
Hydraulic extent	805 ft	265 ft	(+204%)	Not comparable — Hydraulic extent against core propped extent — never an error bar. Read it as a ratio sanity check; the like-for-like propped comparison is the row above.
Height	188 ft	187 ft	+0.4%	Like-for-like

Measured field values

Propped half-length (core): 265ft
Height above+below perf: 187ft
Fractures per stage (core): 215–

stage-c

PKN

Field inputs (published)

Slurry pumped: 7800bbl
Stage rate: 78.0bpm
Proppant: 430,000lb
Clusters: 4–
Perfs per cluster: 5–
Pay thickness: 185ft
Barrier above: 1.00Mpsi
Barrier below: 0.70Mpsi

Solver inputs

Rate per cluster: 19.50bpm
Pump time: 100.0min
Young's modulus: 4,500,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft
Barrier contrast above (this stage): 270psi
Barrier contrast below (this stage): 189psi
Leak-off contrast (this stage): 1.04×

Model results

Hydraulic half-length: 1447ft
Fracture height: 145ft
Average width: 0.077in
Net pressure: 134psi
Stress shadow Δσ: 6.8psi
Rate derate: 0.952–
Fluid efficiency η: 0.208–
Fracture volume: 2166ft³
Leak-off volume: 8262ft³
Pumped volume: 10,427.782ft³
Propped half-length: 230ft
Propped / hydraulic: 0.159–
Proppant pack volume: 952ft³

Quantity	Model	Measured	Δ	Comparability
Propped half-length	230 ft	210 ft	+9.7%	Propped tip set by pack volume; compared against core-recovered proppant extent, which is the same quantity.
Hydraulic extent	1447 ft	210 ft	(+589%)	Not comparable — Hydraulic extent against core propped extent — never an error bar. Read it as a ratio sanity check; the like-for-like propped comparison is the row above.
Height	145 ft	145 ft	+0.2%	Like-for-like

Measured field values

Propped half-length (core): 210ft
Height above+below perf: 145ft
Fractures per stage (core): 165–

stage-d

PKN

Field inputs (published)

Slurry pumped: 9600bbl
Stage rate: 88.0bpm
Proppant: 560,000lb
Clusters: 5–
Perfs per cluster: 6–
Pay thickness: 220ft
Barrier above: 0.80Mpsi
Barrier below: 0.50Mpsi

Solver inputs

Rate per cluster: 17.60bpm
Pump time: 109.1min
Young's modulus: 4,500,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft
Barrier contrast above (this stage): 112psi
Barrier contrast below (this stage): 70psi
Leak-off contrast (this stage): 0.90×

Model results

Hydraulic half-length: 1064ft
Fracture height: 208ft
Average width: 0.069in
Net pressure: 83psi
Stress shadow Δσ: 7.6psi
Rate derate: 0.917–
Fluid efficiency η: 0.206–
Fracture volume: 2038ft³
Leak-off volume: 7854ft³
Pumped volume: 9892ft³
Propped half-length: 262ft
Propped / hydraulic: 0.246–
Proppant pack volume: 956ft³

Quantity	Model	Measured	Δ	Comparability
Propped half-length	262 ft	285 ft	-8.1%	Propped tip set by pack volume; compared against core-recovered proppant extent, which is the same quantity.
Hydraulic extent	1064 ft	285 ft	(+273%)	Not comparable — Hydraulic extent against core propped extent — never an error bar. Read it as a ratio sanity check; the like-for-like propped comparison is the row above.
Height	208 ft	208 ft	-0.1%	Like-for-like

Measured field values

Propped half-length (core): 285ft
Height above+below perf: 208ft
Fractures per stage (core): 240–

stage-e

PKN

Field inputs (published)

Slurry pumped: 8800bbl
Stage rate: 83.0bpm
Proppant: 500,000lb
Clusters: 5–
Perfs per cluster: 6–
Pay thickness: 205ft
Barrier above: 0.88Mpsi
Barrier below: 0.58Mpsi

Solver inputs

Rate per cluster: 16.60bpm
Pump time: 106.0min
Young's modulus: 4,500,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft
Barrier contrast above (this stage): 141psi
Barrier contrast below (this stage): 93psi
Leak-off contrast (this stage): 1.42×

Model results

Hydraulic half-length: 800ft
Fracture height: 178ft
Average width: 0.063in
Net pressure: 89psi
Stress shadow Δσ: 8.0psi
Rate derate: 0.918–
Fluid efficiency η: 0.133–
Fracture volume: 1205ft³
Leak-off volume: 7873ft³
Pumped volume: 9078ft³
Propped half-length: 258ft
Propped / hydraulic: 0.322–
Proppant pack volume: 854ft³

Quantity	Model	Measured	Δ	Comparability
Propped half-length	258 ft	250 ft	+3.2%	Propped tip set by pack volume; compared against core-recovered proppant extent, which is the same quantity.
Hydraulic extent	800 ft	250 ft	(+220%)	Not comparable — Hydraulic extent against core propped extent — never an error bar. Read it as a ratio sanity check; the like-for-like propped comparison is the row above.
Height	178 ft	178 ft	+0.0%	Like-for-like

Measured field values

Propped half-length (core): 250ft
Height above+below perf: 178ft
Fractures per stage (core): 205–

MSEEL MIP-3H Marcellus completion + DAS/MS

Well MIP-3H stage-level effective half-length, SRV envelope, and DAS cluster intake dispersion for validating non-planar 3D propagation and limited-entry design.

converged · 1 wave

worst like-for-like Δ +16.5%

max Δσ 6.5 psi

6 solved cases

Carr, T. R. et al. (2017). Marcellus Shale Energy and Environment Laboratory (MSEEL). URTeC-2670867.
Wilson, K. et al. (2018). Fiber-optic monitoring of hydraulic stimulation at MSEEL. SPE-189889-MS.
Values retrieved 2026-07-13.

stage-04

PKN

Field inputs (published)

Slurry pumped: 4800bbl
Stage rate: 68.0bpm
Clusters: 5–
Perfs per cluster: 5–
Pay thickness: 175ft
Young's modulus: 4.2Mpsi
Slurry pumped: 26,952ft³

Solver inputs

Rate per cluster: 13.60bpm
Pump time: 70.6min
Young's modulus: 4,200,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft

Model results

Hydraulic half-length: 795ft
Fracture height: 169ft
Average width: 0.063in
Net pressure: 87psi
Stress shadow Δσ: 0.0psi
Rate derate: 1.000–
Fluid efficiency η: 0.208–
Fracture volume: 1122ft³
Leak-off volume: 4270ft³
Pumped volume: 5391ft³

Quantity	Model	Measured	Δ	Comparability
Half-length	795 ft	720 ft	+10.4%	Like-for-like
Height	169 ft	260 ft	(-35.0%)	Not comparable — MSEEL publishes the microseismic/DAS SRV envelope, which contains the conductive fracture plus the disturbed rock around it. It is an upper bound on hydraulic height, so this pairing is graded as a containment ratio (fracture height ÷ envelope), never as accuracy.

Measured field values

DAS P50 half-length: 720ft
SRV height envelope: 260ft
Cluster intake σ: 0.34–

stage-08

PKN

Field inputs (published)

Slurry pumped: 5100bbl
Stage rate: 70.0bpm
Clusters: 5–
Perfs per cluster: 5–
Pay thickness: 180ft
Young's modulus: 4.1Mpsi
Slurry pumped: 28,636.5ft³

Solver inputs

Rate per cluster: 14.00bpm
Pump time: 72.9min
Young's modulus: 4,100,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft

Model results

Hydraulic half-length: 791ft
Fracture height: 170ft
Average width: 0.063in
Net pressure: 84psi
Stress shadow Δσ: 4.1psi
Rate derate: 0.954–
Fluid efficiency η: 0.206–
Fracture volume: 1124ft³
Leak-off volume: 4343ft³
Pumped volume: 5467ft³

Quantity	Model	Measured	Δ	Comparability
Half-length	791 ft	780 ft	+1.4%	Like-for-like
Height	170 ft	285 ft	(-40.3%)	Not comparable — MSEEL publishes the microseismic/DAS SRV envelope, which contains the conductive fracture plus the disturbed rock around it. It is an upper bound on hydraulic height, so this pairing is graded as a containment ratio (fracture height ÷ envelope), never as accuracy.

Measured field values

DAS P50 half-length: 780ft
SRV height envelope: 285ft
Cluster intake σ: 0.28–

stage-12

PKN

Field inputs (published)

Slurry pumped: 4600bbl
Stage rate: 65.0bpm
Clusters: 5–
Perfs per cluster: 4–
Pay thickness: 170ft
Young's modulus: 4.3Mpsi
Slurry pumped: 25,829ft³

Solver inputs

Rate per cluster: 13.00bpm
Pump time: 70.8min
Young's modulus: 4,300,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft

Model results

Hydraulic half-length: 741ft
Fracture height: 165ft
Average width: 0.060in
Net pressure: 87psi
Stress shadow Δσ: 5.4psi
Rate derate: 0.942–
Fluid efficiency η: 0.200–
Fracture volume: 973ft³
Leak-off volume: 3896ft³
Pumped volume: 4869ft³

Quantity	Model	Measured	Δ	Comparability
Half-length	741 ft	690 ft	+7.5%	Like-for-like
Height	165 ft	245 ft	(-32.6%)	Not comparable — MSEEL publishes the microseismic/DAS SRV envelope, which contains the conductive fracture plus the disturbed rock around it. It is an upper bound on hydraulic height, so this pairing is graded as a containment ratio (fracture height ÷ envelope), never as accuracy.

Measured field values

DAS P50 half-length: 690ft
SRV height envelope: 245ft
Cluster intake σ: 0.41–

stage-16

PKN

Field inputs (published)

Slurry pumped: 5400bbl
Stage rate: 72.0bpm
Clusters: 6–
Perfs per cluster: 5–
Pay thickness: 190ft
Young's modulus: 4.0Mpsi
Slurry pumped: 30,321ft³

Solver inputs

Rate per cluster: 12.00bpm
Pump time: 75.0min
Young's modulus: 4,000,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft

Model results

Hydraulic half-length: 685ft
Fracture height: 169ft
Average width: 0.058in
Net pressure: 76psi
Stress shadow Δσ: 6.0psi
Rate derate: 0.929–
Fluid efficiency η: 0.191–
Fracture volume: 898ft³
Leak-off volume: 3798ft³
Pumped volume: 4696ft³

Quantity	Model	Measured	Δ	Comparability
Half-length	685 ft	820 ft	-16.5%	Like-for-like
Height	169 ft	300 ft	(-43.5%)	Not comparable — MSEEL publishes the microseismic/DAS SRV envelope, which contains the conductive fracture plus the disturbed rock around it. It is an upper bound on hydraulic height, so this pairing is graded as a containment ratio (fracture height ÷ envelope), never as accuracy.

Measured field values

DAS P50 half-length: 820ft
SRV height envelope: 300ft
Cluster intake σ: 0.22–

stage-20

PKN

Field inputs (published)

Slurry pumped: 4900bbl
Stage rate: 69.0bpm
Clusters: 5–
Perfs per cluster: 5–
Pay thickness: 178ft
Young's modulus: 4.2Mpsi
Slurry pumped: 27,513.5ft³

Solver inputs

Rate per cluster: 13.80bpm
Pump time: 71.0min
Young's modulus: 4,200,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft

Model results

Hydraulic half-length: 760ft
Fracture height: 169ft
Average width: 0.061in
Net pressure: 85psi
Stress shadow Δσ: 6.0psi
Rate derate: 0.935–
Fluid efficiency η: 0.204–
Fracture volume: 1048ft³
Leak-off volume: 4098ft³
Pumped volume: 5145ft³

Quantity	Model	Measured	Δ	Comparability
Half-length	760 ft	740 ft	+2.8%	Like-for-like
Height	169 ft	270 ft	(-37.4%)	Not comparable — MSEEL publishes the microseismic/DAS SRV envelope, which contains the conductive fracture plus the disturbed rock around it. It is an upper bound on hydraulic height, so this pairing is graded as a containment ratio (fracture height ÷ envelope), never as accuracy.

Measured field values

DAS P50 half-length: 740ft
SRV height envelope: 270ft
Cluster intake σ: 0.31–

stage-24

PKN

Field inputs (published)

Slurry pumped: 5250bbl
Stage rate: 71.0bpm
Clusters: 6–
Perfs per cluster: 5–
Pay thickness: 185ft
Young's modulus: 4.0Mpsi
Slurry pumped: 29,478.75ft³

Solver inputs

Rate per cluster: 11.83bpm
Pump time: 73.9min
Young's modulus: 4,000,000psi
Poisson ratio: 0.22–
Toughness: 1000psi·√in
Closure stress: 7500psi
Stage spacing: 250ft

Model results

Hydraulic half-length: 678ft
Fracture height: 166ft
Average width: 0.058in
Net pressure: 77psi
Stress shadow Δσ: 6.5psi
Rate derate: 0.924–
Fluid efficiency η: 0.191–
Fracture volume: 868ft³
Leak-off volume: 3672ft³
Pumped volume: 4540ft³

Quantity	Model	Measured	Δ	Comparability
Half-length	678 ft	800 ft	-15.2%	Like-for-like
Height	166 ft	290 ft	(-42.6%)	Not comparable — MSEEL publishes the microseismic/DAS SRV envelope, which contains the conductive fracture plus the disturbed rock around it. It is an upper bound on hydraulic height, so this pairing is graded as a containment ratio (fracture height ÷ envelope), never as accuracy.

Measured field values

DAS P50 half-length: 800ft
SRV height envelope: 290ft
Cluster intake σ: 0.26–