Customer story · 3-basin deployment
How a top 25 private producer unlocked 15% cash-flow uplift and cut TRIR 83% — across three basins.
Western Anadarko, Permian, and Wyoming. 4,000+ wells. One unified work-planning loop. 18+ months in production with sustained outcomes.
The Challenge
Three basins. Three data landscapes. One superintendent's whiteboard.
A top 25 private producer operating 4,000+ wells across the Western Anadarko, Permian, and Wyoming basins was running every basin slightly differently — each with its own SCADA deployment, its own production accounting workflows, and its own field crew culture. Rising operational costs and production volatility were compounding across all three.
Prior investments of $10M+ in SCADA and routing systems had failed to produce measurable, sustained performance improvements. Each system did its job in isolation: SCADA generated alarms, CMMS tracked work orders, accounting systems closed the month. But no single view ranked what the field should actually work on tomorrow, scored by cash-flow impact.
Pumpers drove fixed routes. Superintendents prioritized from three different spreadsheets per basin. Engineering recommendations took weeks to translate into daily work. At $55 oil, every barrel of deferred production was a direct hit to cash flow — and nobody had time to rank the 200+ daily alarms by dollar impact.
The Decision
Keep the existing stack. Wire the missing links.
The leadership team was skeptical. They'd seen several prior "operations AI" pitches fall flat in the field. The decisive question they asked us: "Does this require us to rip out Enertia, Peloton, or Ignition?"
No. WorkSync sits on top of the existing stack. Data Hub normalizes SCADA + accounting + asset data into a unified well master; Work Engine ranks every task by cash-flow impact and risk score; Route Optimization maps the ranked list to truck cabs. The named systems stay as systems of record. WorkSync closes the loop between what's happening in the field and what should happen next.
The operations team started skeptical — as one lease operator put it: "We've seen this before. Another app, another promise." The difference, they told us later, was that the ranked list showed up in the truck cab by 6 AM on day one of Week 3 — not six months later in a change- management review.
The Deployment
Basin 1 in 4 weeks. All 3 basins in 12.
Same Data Hub architecture, new source connectors per basin. No rip-and-replace. No 12-month enterprise integration cycle.
Read-only integration to SCADA (Ignition), production accounting (Enertia), and asset lifecycle (Peloton WellView). No changes to source systems. Data Hub stood up in a shared cloud tenancy.
Unified well master across 3 basins into one asset hierarchy. Normalized alarm and downtime taxonomies. First cash-flow scoring model validated on a single-basin pilot slice (Western Anadarko).
First daily work plan delivered to pumpers by 6 AM. Superintendents calibrate the scoring model against their operational judgment. Feedback captured and incorporated same day.
Permian added. Then Wyoming. Same data-hub architecture, new source connectors. Every crew across all 3 basins on the same work-planning loop by end of Week 8.
Operations Dashboard live. Real-time ranking responds to commodity price, weather, crew availability. Safety overlay added — risk-adjusted dispatch. Reporting & Analytics exports to finance.
Agentic work plans re-rank mid-shift as conditions change. Engineering recommendations flow into the daily plan via the closed-loop between SYNC (FlowSync, Forecasting) and OPS. 18+ months in production.
Deployments are faster now.
This customer's Week 0 → Week 12 timeline reflects a 2024 deployment with custom integrations per basin. On today's platform, integration takes less than 1 week, full stand-up 2 weeks, and rollout within 4 weeks. Apply for the Free Pilot to see what your timeline looks like.
The Results
18 months in. Outcomes still compounding.
💰 Cash flow
15%+ sustained free-cash-flow uplift vs pre-deployment baseline. Driven by faster response to high-impact anomalies and systematic elimination of low-value site visits. At 4,000+ wells × avg 15 BOE/day × $55 oil, that's tens of millions annually.
🦺 Safety
TRIR fell from 1.8 to 0.3 over 12 rolling months — an 83% reduction against an industry average that hovers around 1.0. Risk-adjusted dispatch (Field Safety + Work Engine) meant the wrong person never arrived at the wrong asset.
🚚 Efficiency
35% fewer site visits for the same production coverage. 25% less drive time per pumper. 60% reduction in redundant tank gauging — systems of record now reconcile automatically.
🧠 Knowledge capture
Tribal knowledge from the superintendent's whiteboard and the senior pumper's mental model is now encoded in the ranking system. When an experienced pumper retires, their judgment doesn't walk out the door.
🔗 Engineering integration
Engineering recommendations now flow into the daily work plan via FlowSync. Previously took 2–4 weeks to translate an engineering study into field action; now same-day via the prioritized queue.
📈 Scalability
The same Data Hub architecture moved from Western Anadarko to Permian to Wyoming with no re-platforming. Each new basin added in under 4 weeks. Proof the model generalizes across basin geology, formation type, and operating culture.
“Our VP Ops used to spend two hours every morning calling the field to figure out where to send crews. Now the plan is in the truck cab by 6 AM, it updates mid-shift when conditions change, and we're hitting 15% more free cash flow across every basin we've deployed into.”
— Operations leadership · Top 25 private producer · Multi-basin (Western Anadarko, Permian, Wyoming)
See this on your data.
Apply for the Free Pilot. Qualified operators get a 4-week proof of value at no license cost. Integration takes less than a week on today's platform.