A wellhead sits at the top of a producing well, holding back pressures that would otherwise be catastrophic. A hot oiler heats crude so it can flow in cold weather. A pressure vessel has to be re-certified on a schedule or it cannot legally stay in service. None of this looks like the field service most software is built for — a technician, a ticket, a truck roll.
Oil and gas equipment manufacturers and service providers run a small number of very specific, safety-critical maintenance programmes, on assets that are often remote and always expensive to leave down. Generic field service software treats every job the same. The equipment doesn't.
The four programmes that actually make up oil & gas field service
Wellhead maintenance
Xmas tree valves control the flow of oil and gas from the well. They need inflow and pressure testing on a schedule, along with actuation testing and lubrication, to confirm they will seal and open exactly when required. Miss the schedule, and the risk isn't a slow machine — it's a well control incident.
Testing & re-certification
High-pressure equipment carries a re-certification date, not a suggestion. Non-destructive testing (NDT) and hydrostatic testing confirm a vessel or line can still hold the pressures it's rated for. An asset that misses its re-certification window is an asset that has to stop being used — there's no grey area.
Hot oiler services
Hot oilers heat crude and heavy fluids so they can be pumped and transported, especially in cold conditions. They fail at the worst possible time — mid-winter, mid-job — and the response is emergency repair alongside the ordinary cycle of commissioning new units and preventive maintenance on units already in the field.
Corrosion mitigation
Oilfield equipment degrades from the inside out, in ways a visual inspection alone won't catch. On-site inspection, troubleshooting and maintenance for corrosion and asset degradation has to be tracked per asset over years, not treated as a one-off repair.
Why generic field service software falls short here
Standard field service tools are built around a ticket: something breaks, a technician is dispatched, the ticket closes. That model doesn't fit oil and gas equipment for three reasons.
The work is scheduled, not just reactive. Re-certification dates and inspection intervals are known years in advance. If the system can't track and trigger against those dates automatically, someone is tracking them in a spreadsheet — and a missed date is a compliance and safety issue, not just a missed appointment.
The asset, not the ticket, is the unit of record. A wellhead's testing history, an oiler's commissioning date, a vessel's NDT results — these need to live against the specific asset permanently, so the next technician (or auditor) sees the full history, not just the last job.
Remote logistics change the economics. A missing part or a wrong call on a remote pad means a multi-hour round trip, not a quick return visit. Asset management has to get the diagnosis and the parts right the first time.
What connected asset management looks like
ServiceCPQ's approach ties every one of these programmes back to one live model of the equipment in the field:
Asset management gives every wellhead, pump and compressor a permanent record — configuration, testing history, certification dates and open work, in one place, not scattered across inspection reports and spreadsheets.
Field service dispatch runs wellhead maintenance, testing and re-certification, hot oiler services, and corrosion mitigation from the same feed-based technician workflow, so a dispatcher sees urgency and compliance deadlines side by side, not just open tickets.
Quoting and parts are tied to the same asset record, so a re-certification or a hot oiler repair converts into an accurate quote without a separate lookup.
Frequently asked questions
What is asset management for oil & gas equipment? Asset management for oil & gas equipment is a live record of every wellhead, pump, compressor and pressure vessel in the field — its configuration, testing and certification history, and open service work — used to schedule and dispatch maintenance programmes like wellhead testing, re-certification, hot oiler service and corrosion mitigation.
Why can't generic field service software handle wellhead and re-certification work? Generic field service tools are built around reactive tickets. Wellhead maintenance and re-certification are scheduled against known compliance dates years in advance, and the history needs to live permanently against the specific asset. Without that, teams fall back on spreadsheets to track compliance deadlines — a risk in a safety-critical environment.
What is a hot oiler and why does it need special field service handling? A hot oiler heats crude and heavy fluids so they can be pumped and transported, particularly in cold conditions. It needs a mix of emergency repair, commissioning of new units, and preventive maintenance on units already deployed — a different rhythm of work than routine scheduled maintenance.
How does ServiceCPQ support NDT and hydrostatic testing programmes? Every high-pressure asset's re-certification date, NDT results and hydrostatic test history are tracked against its permanent asset record, with dispatch and quoting tied to the same record — so a re-certification job is scheduled, quoted and closed against accurate, current asset data.