EH&S software for oil and gas explained

EH&S software for oil and gas: the categories and what each one covers

"EH&S software for oil and gas" is not one product. It is at least eight categories, from incident management and permit to work through to mechanical integrity, and most operators run three or four of them. This guide maps the categories, names the tools usually found in each, and shows where inspection and asset integrity records belong.

Published 10 Sept 2026

Why the search term is misleading

Nobody sells “EH&S software for oil and gas”. Vendors sell an incident platform, or a permit-to-work system, or a contractor prequalification service, and each markets itself with the same three letters. A buyer who compares them side by side is comparing products that do not overlap. The useful first step is deciding which of the categories below the actual problem sits in.

The categories

1. Incident, hazard and observation management. Near misses, injuries, spills, investigations, root-cause analysis and the corrective actions that follow. This is what most people picture when they hear EH&S software, and where the large suites compete: Enablon, Sphera, Intelex, Cority, VelocityEHS, Benchmark Gensuite, Ideagen, EcoOnline and Evotix among them.

2. Control of work and permit to work. Electronic permits, isolation and lock-out registers, simultaneous-operations checks and job safety analysis tied to a live plant state. Specialist territory, often supplied by the operator’s own control system vendor or by a dedicated e-permitting product.

3. Contractor and competency management. Prequalifying contracting companies and verifying that the individuals arriving on site hold current tickets. ISNetworld, Avetta and Veriforce dominate here. Note what this category does and does not do: it verifies that a certificate exists, but it is the contractor’s own system that has to keep the certificate from expiring in the first place.

4. Process safety and mechanical integrity. Inspection data per equipment item held over decades, thickness and corrosion-rate trending, remaining-life and fitness-for-service calculations, risk-based inspection planning. Asset-owner platforms such as GE Vernova APM, PCMS, Antea and Credo sit here.

5. Inspection and NDT job execution. The layer that produces the evidence the mechanical integrity platform consumes: scheduling the inspection, doing it, writing the report, signing it, and proving the technician was certified and the instrument was in calibration on the day. This is contractor and in-house-inspection-team territory, and it is the category AMPS is in.

6. Environmental and emissions reporting. Greenhouse gas inventories, flaring and venting, leak detection and repair, discharge consents and spill reporting.

7. Occupational health and industrial hygiene. Exposure monitoring, noise and dust surveys, health surveillance and fitness for duty.

8. Audit, inspection and CAPA management. Internal and external audits, findings, non-conformance reports and corrective and preventive actions tracked to closure. Sometimes a module of category 1, sometimes a standalone quality system.

Where inspection records become a safety matter

Mechanical integrity is not adjacent to process safety, it is part of it. The OSHA Process Safety Management standard names it as a required element and asks for documented inspection and testing on a schedule consistent with recognised engineering practice, performed by trained personnel, with deficiencies corrected before equipment returns to service. API 510 for pressure vessels, API 570 for piping and API 653 for storage tanks set those intervals.

Everything that requirement asks for is a record: the inspection happened, on this date, on this equipment item, by this technician, whose Level II certification was valid, using an instrument whose calibration certificate had not expired, and the finding was closed out. When an equipment failure is investigated, the failure is usually traced back to one of those records being missing, late or lapsed rather than to a technique being wrong.

What to check before buying, in any category

Capture at source. Records typed up from paper a week later are the records that go missing. The system has to work on a phone at the equipment.
Expiry before the fact. A certificate register that lists expiry dates is not the same as one that warns you a month out. The first is a report, the second prevents the finding.
A trail an assessor can follow. Being able to open one asset and see every job, report, photo and signature against it is worth more in an audit than a search across four systems.
Exit terms. Ask where the documents physically live and what happens to them if you leave. If the answer is “on our servers, submit an export request”, weigh that.

Where AMPS fits, and where it does not

AMPS is in category 5, with a foot in categories 3 and 8. It runs inspection and NDT jobs from creation through to a signed report generated from your own Word template, holds every job on the asset’s own history behind a QR code, tracks personnel certifications and equipment calibration with a one-month expiry flag, and keeps non-conformance records with an audit trail of what was done and by whom. Documents are written to your own OneDrive, SharePoint or Google Drive rather than to AMPS servers, so an existing QA folder structure keeps working and the evidence stays yours.

AMPS does not report incidents, issue permits to work or calculate emissions. Operators who need those run a suite from category 1 or 2 and keep the inspection evidence in AMPS, which is the arrangement most inspection contractors and in-house integrity teams end up with anyway.

Key facts

EH&S (environment, health and safety), also written HSE or HSSE, spans incident management, control of work, contractor and competency management, process safety and mechanical integrity, environmental reporting, occupational health, training records and audit or CAPA management

Mechanical integrity is an explicit element of the OSHA Process Safety Management standard (29 CFR 1910.119(j)), which is why inspection and test records sit inside the EH&S scope rather than beside it

Most incidents traced to equipment failure are traced to an inspection that was late, a technician whose certification had lapsed, or a gauge that was out of calibration: all record-keeping problems

A full EH&S suite and an inspection management system solve different problems; buying one expecting the other is the most common mistake in this category

AMPS covers the inspection, asset integrity and competency-record side, not incident reporting or permit to work

Frequently asked questions

What does EH&S software do in oil and gas?

EH&S software records and controls the activities that keep people, plant and the environment safe: reporting incidents and near misses, issuing permits to work, verifying that contractors and their technicians are competent and current, proving that pressure equipment has been inspected and is fit for service, reporting emissions and spills, tracking occupational exposure, holding training and certification records, and running audits with corrective actions to closure. No single product does all of it well, so operators typically run an incident and audit platform, a control-of-work system, a contractor prequalification service and an asset integrity or inspection system alongside each other.

Is EH&S software the same as HSE software?

Yes. EH&S (environment, health and safety) is the common term in North America, HSE (health, safety and environment) is more common in Europe, the Middle East, Australia and New Zealand, and HSSE adds security. Vendors use the labels interchangeably, so a search for either returns the same products.

Why do inspection and NDT records count as EH&S?

Because mechanical integrity is a named element of process safety. The OSHA Process Safety Management standard requires written procedures, trained personnel, documented inspection and testing on a schedule consistent with recognised engineering practice such as API 510, 570 and 653, and correction of deficiencies before further use. Each of those is a record that must exist and be produced on demand, which is why an inspection management system carries EH&S weight even though it is not marketed as EH&S software.

What should an oil and gas operator look for when buying?

Decide which category the actual problem falls into before looking at products. Then check four things regardless of category: whether records are captured where the work happens rather than typed up later, whether expiry and due dates are flagged before they lapse rather than discovered in an audit, whether an assessor can be shown a complete evidence trail without a manual search, and whether your data leaves with you if you change vendors.

Does AMPS replace an EH&S suite?

No, and it is not sold as one. AMPS has no incident reporting, no permit to work and no emissions module. What AMPS covers is the inspection and asset integrity side: inspection and test jobs from creation to report, a job history on every asset, personnel certificates and equipment calibration with a one-month expiry warning, non-conformance records, and an audit trail of what was done, by whom and when. Operators typically run it alongside an incident and audit platform rather than instead of one.