Pad operations control

Live channels belong on Frac van live. This page is the shift-level view above it: every stage on the pad reconciled against its design — placed proppant and fluid, average rate, pressure headroom, cycle time and logged downtime — rolled up into pad pace, projected finish, and non-productive time by reason. Each deviation carries the response steps a supervisor can work through, and both tables export to CSV for the daily pad report.

Pad status

Stages complete: 3/10; 30% of pad · 1 aborted
Pace: 7.8 stages/day; 186 min observed cycle
Projected remaining: 18.6 h; At the observed cycle, not the design clock
Non-productive time: 15.1%; 126 min of consumed clock
Schedule: On pace; Consumed clock vs design clock on started stages
Placed vs design: 97% prop · 100% fluid; Completed stages only

Stage ledger — plan vs actual

Stage	Pump min	Placed	Cycle	Severity
Snark 3H · 1	/ 105	100%	160 min	ok
Snark 3H · 2	/ 105	91%	215 min	action
Snark 3H · 3	/ 105	47%	174 min	action
Snark 3H · 4	/ 105	43%	103 min	ok
Snark 3H · 5	/ 105	—	—	ok
Snark 4H · 1	/ 105	100%	182 min	watch
Snark 4H · 2	/ 105	—	—	ok
Snark 4H · 3	/ 105	—	—	ok
Snark 4H · 4	/ 105	—	—	ok
Snark 4H · 5	/ 105	—	—	ok

Pump minutes show actual / design. Cycle time is pump + turnaround + downtime, compared against the design clock for that stage.

Downtime by reason

Screen-out recovery58 min · 46% · 1 stage(s)
Sand supply42 min · 33% · 1 stage(s)
Wireline / perforating26 min · 21% · 1 stage(s)

Deviations & response playbooks

watch
Proppant shortfall — Snark 3H stage 2
Placed 91.1% of design proppant.
1. Confirm the blender totalizer against the sand-coordinator ticket before crediting the stage.
2. Check screen-out / pressure-limit history on the stage — placement loss usually pairs with one.
3. Carry the shortfall into the next stage design only if the wellbore is clean; otherwise re-design the diversion.
watch
Rate below design — Snark 3H stage 2
Average slurry rate held 92.9% of the designed rate.
1. Verify online pump count and any unit derate before treating it as a formation response.
2. Compare surface pressure at the reduced rate — pressure-limited vs equipment-limited changes the fix.
3. If formation-limited, re-cut the rate schedule and update the treating-pressure forecast for the remaining stages.
action
Stage cycle overrun — Snark 3H stage 2
Stage cycle 134.4% of design clock (215 min consumed, 42 min downtime).
1. Split the overrun into pump, wireline and downtime before assigning it to a crew.
2. Re-time the remaining stage plan with the observed cycle so the pad ETA stays honest.
3. Escalate to the pad coordinator if the overrun is repeating on the same crew change.
action
Rate below design — Snark 3H stage 3
Average slurry rate held 84.7% of the designed rate.
1. Verify online pump count and any unit derate before treating it as a formation response.
2. Compare surface pressure at the reduced rate — pressure-limited vs equipment-limited changes the fix.
3. If formation-limited, re-cut the rate schedule and update the treating-pressure forecast for the remaining stages.
action
Pressure near limit — Snark 3H stage 3
Peak treating pressure reached 98.3% of max allowable.
1. Hold rate and confirm the max allowable against the wellhead / casing rating in the job program.
2. Step down rate and log the step-down response — it doubles as near-wellbore friction data.
3. If the limit repeats, add friction reducer or perf-friction relief before the next stage rather than derating mid-stage.
watch
Stage cycle overrun — Snark 4H stage 1
Stage cycle 113.8% of design clock (182 min consumed, 26 min downtime).
1. Split the overrun into pump, wireline and downtime before assigning it to a crew.
2. Re-time the remaining stage plan with the observed cycle so the pad ETA stays honest.
3. Escalate to the pad coordinator if the overrun is repeating on the same crew change.
watch
Downtime concentrated in screen-out recovery
Screen-out recovery owns 46% of pad downtime (58 min over 1 stage(s)).
1. Open a single-cause review on the dominant reason code rather than spreading the fix.
2. Confirm the logistics or maintenance owner and set a next-shift commitment.
3. Track the reason on the daily pad report until its share drops below the callout threshold.

Live stage projection

Snark 3H stage 3 is pumping. Placement pace is extrapolated to the end of the stage so a shortfall is called while there is still stage left to fix it.

Watch

Watch: Projected proppant 91% of design

Stage progress (fluid placed)52%

Elapsed pump (min)

Fluid to date (bbl)

Proppant to date (lb)

Rate now (bpm)

Surface pressure (psi)

Projected pump time: 112 min; +7 min vs design
Projected proppant: 400,000 lb; 91% of design
Rate adherence: 95%; 81 of 85 bpm
Pressure headroom: 92%; limit 10,500 psi

• Projected proppant 91% of design
• Surface pressure at 92% of max allowable

Pad finish forecast

5 of 5 stages left · 12.5 h remaining at 160 min/stage · On the design clock.

Assurance layer

Every deviation carries a named acknowledgement and, at action severity, an engineer approval before the pad moves on. Alongside it: offset-well gauge response during pumping classified into trend versus frac hit, and per-feed ingest health that is graded on cadence and completeness rather than on which vendor sent it.

Next-stage assurance gate

2 blocker(s)

• 2 action-severity deviations without engineer sign-off.
• 1 offset well in frac-hit response.

Deviation acknowledgement & approval

Open

Overdue

Mean time to ack

7 min

Approval gaps

Finding	Severity	Age	Status	Needs	Last signature
Proppant shortfall — Snark 3H stage 3	action	115 min	acknowledged	engineer	R. Diaz — Flushed and swapped to 40/70 for the tail-in.
Pressure near limit — Snark 3H stage 4	watch	32 min (overdue)	open	supervisor	—
Rate below design — Snark 4H stage 2	action	19 min (overdue)	open	engineer	—

Action-severity deviations need engineer sign-off; watch-level needs a supervisor. Closing below that level is recorded as an approval gap rather than silently accepted.

Offset-well monitoring during pumping

1 offset well showing frac-hit response — intervene before the next stage.

Offset well	Spacing	Rise	Rate	Per 1,000 ft	Response	Recommended action
Snark 1H	880 ft	225 psi	185 psi/hr	255.68 psi	frac-hit	Frac hit on Snark 1H — shut in or choke back the offset, drop stage rate, and cut proppant concentration before continuing.
Snark 2H	1650 ft	58 psi	34 psi/hr	35.15 psi	pressure-trend	Pressure trend on Snark 2H — keep the gauge on a 1-minute scan, flag the next two stages, and pre-stage a rate step-down.
Snark 5H	2620 ft	2 psi	1 psi/hr	0.76 psi	no-response	No measurable response on Snark 5H — continue as designed and keep monitoring.

Vendor-neutral ingestion status

Live feeds

3/5

Degraded

Completeness

98.5%

Vendors / protocols

4 / 4

Channel	Vendor	Protocol	Health	Sample age	Complete	Note
Chemical totals	Chem Vendor C	CSV drop	stale	1800s	77.8%	Planned outage — excluded from ingest trust.
Offset gauge pressure	Gauge Vendor B	MQTT	stale	46s	90.7%	Behind by 4.6× cadence at 90.7% completeness.
Slurry rate	Pumper Data Co	WITSML	live	3s	98.5%	On cadence, 98.5% complete.
Treating pressure	Pumper Data Co	WITSML	live	2s	100%	On cadence, 100% complete.
Disclosure records	FracFocus	FracFocus	live	240s	100%	On cadence, 100% complete.