NORMAL
Continue under the current operating plan.
Monitor the live feed.
● WELLS SPECIAL OPERATIONS / LIVE BHA MONITORING
SEE THE TRIP
BEFORE IT
HAPPENS.
DONTTRIP
MODEL CLASSCUSTOM / OPERATOR-BUILT
COMMISSIONING TARGET90%+ AGREED ACCURACY
ACTION HORIZONT–6 HOURS OR LESS
A custom-built BHA failure model, made operational on your existing EDR stream and commissioned to a 90%+ agreed decision-accuracy target. One decision-grade signal: 0 NORMAL. 1 FAILURE IMMINENT / T–6 HOURS OR LESS.
90%+ TARGET VALIDATED ON YOUR RETROSPECTIVE + SHADOW DATA AT THE AGREED ≤6-HOUR ACTION HORIZON BEFORE THE MODEL IS ARMED.
Ease the BHA. Assess POOH. Preserve the tool before failure makes the decision for you.
LIVE OPERATING LAYER / BASIN 01MODEL DT-BHA / 01SECURE FEED
RIG 04 / MIDLAND DEMO EDR STREAMING / 1 SEC≤6H HORIZON ARMED
MODELDT-BHA / CUSTOM
STATE AGE00:00
SOURCE RATE1.0 HZ
HISTORYCONTINUOUS
FAILURE IMMINENT0
NO ≤6H FAILURE WINDOW DETECTEDHOLD CURRENT OPERATING PLAN
GREEN HISTORY → RED LIVE STATE / MIN 2 RED-LABEL INPUTS1-SEC SOURCE / DEMO ACCELERATED — HUMAN AUTHORIZATION REQUIRED
FLAT FLEET PRICE$19,999/MO
ONE-BASIN SCOPEUNLIMITED RIGS + WELLS
COMMITMENTCANCEL ANYTIME
5% FASTER MONTHLY LATERAL CYCLE TIME — OR FULL REFUNDLocked pre-rig-up six-month baseline. Comparable lateral sections. Agreed exclusions.
01ONE DECISION-GRADE SIGNAL
02UNLIMITED RIGS + WELLS / ONE BASIN
0314-DAY MAX RIG-UP
04NO BILL UNTIL RIG-UP ENDS
01 / THE DECISION
THE TRIP IS EXPENSIVE.
THE DECISION BEFORE IT
IS INVALUABLE.
BHA failure forces a trip after the value has already been destroyed. DONT TRIP moves the decision upstream—while the driller can reduce operating severity and leadership can assess pulling out before complete failure.
FAILURE IMMINENT
Projected failure window: six hours or less.
Go easier on the BHA and assess POOH.
Preserve tool quality and lateral time.
02 / THE SYSTEM
LIVE FEED IN.
ONE DECISION OUT.
DONT TRIP is designed around the feed you already have. Connect live drilling data, customize each role’s view during rig-up, and deliver one auditable decision point back to the team.
LIVE EDR
Use your existing rig feed. No additional vendors required.
CUSTOMIZE
Each directional driller, drilling engineer, and company man can customize the view they use.
MONITOR
A custom monitoring model evaluates each rig.
SIGNAL
0 NORMAL / 1 FAILURE IMMINENT within the agreed ≤6-hour horizon.
ACT
Reduce severity or assess POOH under operator procedures.
03 / WELLS SPECIAL OPERATIONS
A COMMON OPERATING PICTURE FOR BHA RISK.
UNLIMITED RIGS + WELLS. ONE BASIN.
WELLS SPECIAL OPERATIONS / FLEET MONITORILLUSTRATIVE DEMO
LAST SYNC / 00:03
UNITFEED HEALTHMODEL STATEASSIGNED ACTION
RIG 01 STREAMING0 / NORMALHOLD PLAN
RIG 02 STREAMING0 / NORMALHOLD PLAN
RIG 03 STREAMING0 / NORMALHOLD PLAN
RIG 04 STREAMING1 / FAILURE IMMINENTREDUCE SEVERITY / ASSESS POOH
RIG 05 STREAMING0 / NORMALHOLD PLAN
04 / CONNECT
KEEP THE FEED.
ADD THE DECISION.
DONT TRIP is designed to sit above live drilling feeds, not force a rip-and-replace. During rig-up, we map available EDR traces, units, rig states, and delivery path into one production monitoring layer.
Provider-agnostic by design. Final compatibility is confirmed during technical discovery.01EDR API↗
02FAILURE DATA HISTORIAN↗
03STREAM↗
04SECURE FILE / BRIDGE↗
05OPERATOR DATA PLATFORM↗
05 / RIG-UP
YOUR TEAM. OUR ENGINEER.
LIVE IN 14 DAYS OR LESS.
A forward-deployed engineer works directly with drilling, RTC, data, and field teammates through connection, role-based customization, shadow monitoring, and handoff. The first bill is not issued until the rig-up period ends.
CONNECT
Confirm feed access, run definitions, users, and baseline.
CUSTOMIZE
Map the feed, then tailor the monitoring view for each operational role.
SHADOW
Monitor beside the existing workflow and review the signal with the team.
ARM
Deliver the 0/1 decision state into the agreed operational surface.
06 / THE GUARANTEE
5% FASTER.
OR FULL REFUND.
Improve monthly average lateral-section cycle time by at least 5% against a baseline locked from the six calendar months immediately before rig-up—or receive a full refund of that month’s platform fee. Start and end markers, lateral length, and program are normalized during rig-up. Unrelated NPT is excluded; BHA-related trip and failure time stays in.
LOCK 6-MONTH BASELINE→NORMALIZE PROGRAM→MONITOR MONTH→REFUND IF <5%
07 / TIME IS THE UNIT
WHAT 5% CAN
BE WORTH IN
MIDLAND.
The six calendar months immediately before rig-up set—and lock—the guarantee baseline. The observed Midland result below is only an anchor for translating a 5% lateral-section improvement into direct rig-time OPEX.
OBSERVED MIDLAND ANCHOR / NOT YOUR BASELINE OR A CUSTOMER RESULT
OBSERVED ONE-RUN RESULT4.52 DAYS16,101 ft curve + lateral production section
5% OF OBSERVED DURATION5.4 HOURS0.226 day per qualifying lateral
ALL-IN SPREAD-TIME EQUIVALENT$22.6K–$28.3Kper lateral at $100K–$125K/day
8 QUALIFYING LATERALS / MONTH$180.8K–$226Killustrative monthly drilling-spread OPEX equivalent
Observation: Baker Hughes reported a 16,101-ft Midland Basin curve and lateral production section drilled in one run over 4.52 days; it is a case result, not a basin average. The $100K–$125K/day input is an all-in Permian drilling-spread proxy—not the bare rig contractor dayrate. Permian Resources used that range while comparing its drilling with faster Midland operators; H&P independently publishes an $80K–$140K/day Permian operating-cost range. Actual avoidable OPEX depends on contract structure and released billable time. Baker Hughes case ↗ Permian Resources call ↗ H&P benchmark ↗
MEET THE FOUNDER
BUILT FROM THE
REAL-TIME CENTER OUT.
LEONARDO RUELAS JR.
DONT TRIP is being built by a petroleum engineer who understands the handoff between live drilling data and the people accountable for the next decision.
MEET LEONARDO ON LINKEDIN ↗FIELD QUESTIONS
THE STRAIGHT
ANSWERS.
01What does DONT TRIP output?+
One binary operational state: 0 NORMAL or 1 FAILURE IMMINENT. State 1 represents a projected failure window of six hours or less; that action horizon is calibrated and validated during commissioning.
02Does it replace the driller or company man?+
No. DONT TRIP provides a decision point. Qualified personnel retain authority and operator procedures govern every action.
03Which EDR systems do you support?+
We are designed to work with the feed you already have—including Nabors RigCLOUD, ROGII DrillSpot / Solo Cloud, Pason, Corva, NOV WellData / RigSense, SLB DrillOps, WITSML platforms, and custom bridges. Final compatibility is confirmed during discovery.
04How long does rig-up take?+
No more than 14 days under this offer, assuming agreed feed access and active operator collaboration.
05When does billing begin?+
At the end of rig-up—not before.
06How is the 5% guarantee measured?+
Against a baseline locked from the six calendar months immediately before rig-up for comparable lateral sections, normalized for lateral length and program. Unrelated NPT is excluded; BHA-related trip and failure time remains included.
07What if performance improves by less than 5%?+
The applicable monthly platform fee is refunded under the contract’s agreed measurement terms.
08Is pricing per rig?+
No. $19,999 per month covers unlimited rigs and unlimited wells within one contracted basin.
09Can we cancel?+
Yes. Cancel anytime, subject to the agreement.
10What data do you need?+
A usable live EDR feed, trace and unit definitions, rig activity context, BHA and run context, and operator counterparts for rig-up.
08 / REQUEST ACCESS
RIG UP BEFORE
THE NEXT TRIP.
Tell us how your rigs stream live drilling data. We’ll confirm technical fit, baseline the guarantee, and define the 14-day rig-up.
BEST FIT
Operators with active lateral programs, a usable live EDR feed, and a team ready to validate an operational signal.