Oilfield Equipment Tracking: Certifications, Inspections and Custody Across Basins

Most advice on tracking oilfield assets starts and ends with GPS: tag the trailer, draw a geofence, watch the dots. Our guide to tracking equipment across jobsites covers that ground. But for a pressure control or rental tool fleet, where a unit sits is rarely what holds up a job.

Picture a rental tool and pressure control company running three yards across the Permian and the Eagle Ford. A coordinator pulls a frac stack for a Monday job because the yard map shows it racked, tested and ready in Bay 4. On Sunday night, a yard hand cross-checking paperwork finds that the stack's wing valve was swapped in from another assembly after its last job, and that valve's certificate lapsed the week before. The stack can't go, a replacement gets hot-shotted from another yard, and the crew rolls out, say, five hours late with the company man asking why. After that, the company moved every certificate and test chart onto the valve's own serial record, so a component swap carries its paperwork with it.

If you run fleets across more than one yard, here's what to record for every serial, where certification tracking breaks, and how to set it up in six steps.

Overview:

• Location tells you where a unit is. Certification, inspection and custody records tell you whether it can go to a job.

• Track at serial level, including components inside assemblies, so a stack can't look certified while one valve inside it is overdue.

• Check every due date against the planned job end plus a buffer, not against today.

• Treat yard-to-yard moves as transfers with a sender and a receiver, and review exceptions every week.

What is oilfield equipment tracking?

Oilfield equipment tracking is keeping one current record for every serialized asset: where it is, which job or crew has it, whether its certification is valid, when it was last inspected and what repairs it's had. GPS answers the first question. Your records have to answer the rest before anything goes out the yard gate.

Operations managers, yard leads, dispatchers and the shop all work from that record, and customers and auditors read it too. In most companies the pieces live in different tools: a CMMS for maintenance, a spreadsheet for certificates and a GPS portal for trailers. That's part of why CMMS, EAM and FSM systems get confused so often. Tracking works when one serial number ties them together.

Why isn't GPS tracking enough for oilfield equipment?

GPS tells you where a tagged asset is, which matters for trailers, skids and anything on a truck. It can't tell you whether a valve's certificate is current, whether a spool passed its last pressure test or which stack a component went into. For pressure control and rental tool fleets, those records decide whether an asset can go out.

These are the questions that actually hold up a job:

• Is the certification current, and will it still be current when the job ends?

• When was it last inspected, by whom, and did it pass?

• Which job, crew or customer has it right now?

• Has it been repaired or had parts swapped since the last test?

• Is it ready, or has it just come back?

A tag on a valve body tells you where the valve is, not that it's out of cert. That status lives in certificates, test charts and shop records, usually kept apart from location data. Here's how the tracking job changes by asset class.

What most teams miss is the middle of that table. GPS earns its place on road units, but the iron, the valves and the well control equipment are where a missing record turns into a turned-around crew.

What should you track for every oilfield asset?

Track eleven fields per serial: identity, class and rating, parent assembly, location, custody, status, certification, inspection and test history, repair history, usage and documents. Each one answers a question a dispatcher, yard lead, customer or auditor will ask, so a blank field is a question nobody can answer when it comes up.

The same fields work for rental tool tracking: swap stages for rental days or runs. If you also run the rental side of the business, our guide to equipment rental business software covers availability and billing.

Ratings deserve more care than they usually get. API published Spec 7HU2 for oilfield hammer unions in March 2022, in response to industry calls for higher standards for hammer union components and how they fit together, to improve safety and prevent failures. Put the rating and figure number on each serial record, not just stamped on the iron.

The usage field is the one most spreadsheets skip, and it's the one that lets you move from calendar intervals to wear-based ones. Our guide to predictive vs proactive maintenance covers when that switch pays off.

What the record looks like on a Monday pull list

Here's how the record earns its keep on a normal Monday. It's 6:30 a.m., and the yard lead has a pull list for three jobs going out by noon. Instead of walking the bays with a clipboard, she filters the register by Reserved and by this week's job numbers.

First, she checks the flags. Two items show as due before job end: a plug valve whose certificate lapses on day four of a frac job, and a spool waiting on a retest after a seat replacement. Both get swapped for certified spares from the next bay, and the shop gets the originals along with the date they need to be back.

Next, she scans each item as it's loaded. The scan moves it from Reserved to In transit with her name, the time and the trailer number, so the dispatcher can see what has actually left the yard.

Then she looks at what came back over the weekend. Anything in Returned stays put until it's inspected, and nobody pulls it for Tuesday just because it looks clean. By 8 a.m., the coordinator has a list of what shipped, what got swapped and why, and nobody has opened a binder.

Still matching certificates to serials by hand? 
Equipt keeps certification tracking and automated reminders on each asset record, and crews update it offline from location. 
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Where does equipment certification tracking break down?

Certification tracking usually breaks in four places: the certificate is filed with a job instead of the serial, components move between assemblies without their paperwork, due dates get checked against today instead of the job end, and every yard keeps its own tracker. Spreadsheets fail here first because none of those links survive a copy and paste.

Example: checking one frac stack against the job end

Now let's look at an example of the third pattern.

All company names, people, numbers and rates below are fictional and for illustration only.

ABC Pressure Control has frac stack FS-00 reserved for job J-0000, planned for 2 Nov to 13 Nov 2026. With a 3-day buffer for delays, every component has to stay certified through 16 Nov 2026. The stack passed its assembly test on 20 Oct 2026, and the coordinator runs the check on 26 Oct 2026.

Two of five components fail, even though the assembly passed its test six days earlier, and a stack-level check would have sent both out.

Recertification intervals: what the rules say and what decides the date

That depends on the equipment type, the OEM's guidance, the standards you work to and what your customers require. As one reference point, DNV recommends that blowout preventers and well pressure control equipment be recertified at least every five years.

Set the reminder window by your slowest step, not by habit. If an outside shop takes three weeks to recertify a valve and getting it there takes another week, a 30-day reminder is already too late. Start at 60 days for outside recertification and 30 for in-house tests, then adjust once you've timed a few real round trips.

Whatever intervals your program sets, the tracking job for pressure control equipment recertification is the same: store the due date on each serial and act well before it arrives.

How do you set up oilfield equipment tracking, step by step?

Set it up in six steps: build a serial-level register starting with your riskiest classes, define statuses and the rules between them, attach every certificate and inspection to the serial, record custody at every handoff, check certifications against the job schedule before dispatch, and review exceptions every week.

Step 1: Build the register at serial level, riskiest classes first

Don't load the whole fleet at once. Start with pressure-rated equipment, then the rental tools that go out most often. Pull serials from your current spreadsheets, OEM paperwork and the last physical count. Where the spreadsheet and the yard disagree, the yard wins: walk each bay, count what's there and fix the record. Give every item a tag (QR code, barcode or RFID) linked to its serial.

Step 2: Define statuses and the rules between them

Keep the list short: Ready, Reserved, In transit, On job, Returned, In inspection, In shop, Quarantined and Retired. Then write the rules. Equipment moves from Returned to Ready only when a passed inspection is attached. Anything with an expired certificate goes to Quarantined, wherever it is.

Status rules matter most when more than one company shares the fleet. One multi-entity equipment rental and service group, an oilfield services provider with a parent company and a subsidiary, tracked asset availability and return status by phone or email, which risked double-bookings and missed revenue. On Equipt, dispatch and returns sync to both entities with shared documents and real-time notifications.

Step 3: Attach every certificate and inspection to the serial

Each certificate gets its number, issue date, next due date and the file itself. Each inspection gets the date, the inspector, the result and the test chart or readings. These equipment inspection records belong on the asset, not in a job folder.

Running inspections as digital work orders helps here, because the result lands on the serial when the inspector closes the work. Start reminders 60 days out for outside recertification and 30 days out for in-house tests, so items reach the shop before the next job needs them.

Step 4: Record custody at every handoff

Yard check-out, arrival on location, transfer between jobs, pickup and return each get a scan on a phone, with the time, the person and the place. Plenty of wellsites have weak or no signal, so the app has to capture offline and sync later. One missed transfer makes the record wrong for everyone who reads it after that.

Offline capture is also a fair first test for any intelligent field operations software on your shortlist: take a device out of coverage, scan three handoffs and watch what syncs.

Step 5: Check certifications against the job schedule before dispatch

When a coordinator builds the equipment list for a job, flag any serial whose certification or next inspection falls due before the planned end date, plus a buffer for delays. Swap it at planning time, not on location. It's the same readiness check that runs through the whole oilfield dispatch workflow before a job is released.

Step 6: Review the exceptions every week

One short meeting, one list: certificates due in the next 60 days, assets stuck in Returned or In inspection, assets still on location after the job closed, and items with no scan in 30 days. Every line gets an owner and a date.

If the Returned pile keeps growing, our post on why returned equipment sits idle walks through the turnaround fixes.

For the inspection tasks themselves, what to check daily, weekly and before deployment, use our oilfield equipment maintenance checklist. Tracking makes sure each inspection lands on the right serial.

How do you track equipment across multiple yards and basins?

Use one register, one set of status names and one owner per yard, and treat every yard-to-yard move as a transfer with a sender and a receiver. Then look across basins before you rent or rush a recertification, because the equipment you need may already be certified and idle in another yard.

• Use one register and one vocabulary. The same asset classes and status names in every yard. “Ready” in Midland has to mean exactly what it means in Pleasanton.

• Name an owner per yard. That person owns record accuracy and gets the weekly exception list.

• Treat yard-to-yard moves as transfers. A transfer has a sender and a receiver. Editing a location field doesn't.

• Look across basins before you rent or rush. When the shared view shows certified, idle equipment in one yard and a request in another, a transfer can replace a third-party rental or an expedited recertification.

• Report by basin and asset class. Certificates due, items in the shop and utilization side by side show which yard is short and which has spare equipment.

“We’re now able to quickly redeploy equipment between locations, reducing equipment costs while maintaining the high level of responsiveness our customers expect.”
— Brendan Araujo, Production Manager, Innovex

That shared view is what oil and gas asset tracking software should give you: live inventory, transfer and utilization visibility across remote sites, so the transfer gets planned before anyone calls a rental company.

What should an equipment certification tracker include?

A certification tracker needs one row per serialized item, the certificate due date and recertification type, the last inspection and its result, the planned job end, and two automatic checks: valid through the job end plus a buffer, and inside the reminder window.

If you build it in a spreadsheet, give it four tabs:

• Register: one row per serial, from asset ID to notes, with dropdowns for status, recertification type and inspection result, and flags for DUE BEFORE JOB END, BOOK RECERT NOW and EXPIRED: QUARANTINE.

• Example: a worked case, like the FS-00 stack above, so new users can see how the flags work.

• Status rules: the nine statuses, what each one means and which moves are allowed.

• How to use: which cells to fill and how to set the reminder windows and buffer.

Add summary cells that count the assets listed, items due before job end, expired items and items to book for recertification, plus a check cell that counts rows missing a due date. That one should always read zero.

When should you move equipment tracking off spreadsheets?

Move off spreadsheets once you run more than one yard, swap components between assemblies, get asked for certificate packs before jobs, or have several people editing the same file. A spreadsheet can carry one yard and a few hundred serials if one disciplined person owns it. Past that, the links between records start breaking.

Score two or more and the spreadsheet is likely costing you more than it saves. Here's the honest trade-off, though: software won't fix a register nobody keeps current, and if the yard doesn't scan at handoffs, any tool will just be wrong faster. Get the six steps running on a spreadsheet first.

At that point, asset management software for oil and gas keeps the serial-level record, the certificate and inspection history and the custody trail in one place, with reminders tied to due dates and offline capture for crews on location.

One pressure control equipment service provider moved equipment movements, inspections and certifications off spreadsheets and paper into one system that tracks every frac stack, valve and manifold assembly with location, condition, readiness and certification status. Maintenance schedules and certification renewals now run on usage and condition data, with automated reminders.

If you're comparing tools, test three things with your own data: how each one handles component-level certification, whether field capture works offline, and whether it checks due dates against job dates. Rental tool companies that also bill by the day should check how tracking connects to rental management software.

To see this with your own asset classes and yards, book a demo with the Equipt team.

The bottom line on oilfield equipment tracking

Start where the risk is. Load your pressure-rated equipment at serial level, attach the certificates and test charts to each serial, and make the due-date check run against the planned job end. Those three moves catch the problems that most often get a stack turned around at the yard gate or on location.

Then decide how far the spreadsheet can carry you. If you scored two or more on the scorecard, move to a shared register that every yard writes to from the field, so a component swap, a transfer or a failed test changes the record the moment it happens, and nobody has to merge trackers the night before a job.

Frequently asked questions

What's the difference between oilfield equipment tracking and GPS asset tracking?

GPS asset tracking tells you where a tagged asset is. Oilfield equipment tracking covers location plus custody, certification status, inspection history and repair records for each serial number. For pressure control and rental tool fleets, those extra records usually decide whether an asset can go to a job, so location data on its own isn't enough.

How often does pressure control equipment need recertification?

It depends on the equipment type, the OEM's guidance, the standards you work to and your customers' requirements. As one reference point, DNV recommends recertifying blowout preventers and well pressure control equipment at least every five years. Store the due date your program sets on each serial number and set reminders well before it arrives.

What records should be kept for each piece of oilfield equipment?

Keep the serial number, asset class and rating, parent assembly, location, custody, status, certificate number with issue and due dates, inspection and pressure test records, repair history and usage. Attach the documents themselves, such as certificates and test charts, to the serial record so the evidence moves with the asset instead of staying in a yard binder.

Should you track frac stack components separately or as one assembly?

Track both. Each valve, spool and adapter gets its own serial record with its own certificate and test history, and the assembly record lists which components are installed right now. When a component moves to another stack, update the parent assembly so the certificate follows the component instead of staying with the stack.

How do you track equipment at wellsites with no cell signal?

Use a mobile app that records scans, inspections and handoffs offline and syncs when the device reconnects. Crews scan the asset tag on arrival, at transfer and at pickup, and each event stores the time and the user. Without offline capture, updates wait until someone is back in coverage, and many never get entered at all.