7 Critical CMMS Mistakes in Oil and Gas Maintenance
A CMMS should close the gaps in a maintenance program, not create new ones. These are the seven setup and usage mistakes that cost oil and gas operators the most in downtime, compliance exposure and repair spend — and what to do about each one.
Why These Mistakes Cost More in Oil and Gas
Oil and gas maintenance carries consequences most industries do not. Assets are distributed across wellsites, compressor stations, pipeline corridors and offshore platforms. Much of the equipment is covered by OSHA’s process safety management standard, which turns maintenance records into regulatory evidence. And unplanned downtime is measured in lost production, not just repair cost.
That is why a partly-implemented CMMS is worse than it sounds. Each of the seven mistakes below is common, fixable, and compounding — the longer a bad asset hierarchy or an unconnected inventory system stays in place, the more expensive it becomes to correct.
The 7 Mistakes
1. Relying on Spreadsheets for Maintenance Management
The problem. Maintenance history, work orders and inspection records live in separate spreadsheets on separate sites, often maintained by different people. Nobody has a single view of what has been done to an asset or how often it has failed.
Why it costs you. Recurring failures go unnoticed because no one is looking at the same data. Under OSHA’s process safety management standard, operators covered by 29 CFR 1910.119 must document mechanical integrity inspections and tests on covered equipment — and spreadsheets scattered across sites make producing that record on demand very difficult.1
The fix. Centralize maintenance execution in a CMMS. One system holds work orders, asset history and preventive maintenance schedules, and one query produces the record an auditor asks for. See where spreadsheets break down.
2. No Mobile Access for Field Technicians
The problem. Technicians working on wellsites, compressor stations and pipeline corridors record work on paper, then re-enter it into a system hours or days later — if it gets entered at all.
Why it costs you. Transcription introduces errors and delay. Readings, part numbers and completion times get remembered rather than recorded, and compliance documentation is written after the fact instead of at the asset.
The fix. Give field crews mobile access to the CMMS so work orders are completed at the equipment, with meter readings, photos and parts logged as the work happens.
3. Manual Compliance and Lockout/Tagout Tracking
The problem. Lockout/tagout permits, energy control procedures and periodic inspections are tracked on paper forms and in binders, with no link to the work order that required them.
Why it costs you. OSHA 29 CFR 1910.147 requires documented energy control procedures and a periodic inspection of those procedures at least annually.2 Paper systems make it hard to prove the inspection happened, and harder still to show which procedure was applied to which job.
The fix. Digitize the compliance workflow inside the CMMS so the energy control procedure attaches to the work order, sign-offs are captured in sequence, and the annual inspection record is queryable. See our guide to writing and auditing LOTO procedures.
4. No Integration Between the CMMS and SCADA or Sensor Data
The problem. Condition data lives in the SCADA and historian systems. Maintenance lives in the CMMS. Nothing connects them, so an alarm or a trending vibration reading never becomes a work order.
Why it costs you. The warning arrives and nobody acts on it. Maintenance stays reactive, and problems that were visible in the data for weeks surface as failures. NIST SP 800-82 Rev. 3 also notes that operational technology integrations carry their own security requirements, which is worth planning for before you connect the two systems.3
The fix. Feed condition and alarm data into the CMMS so thresholds generate work orders automatically. That is the foundation of predictive maintenance.
5. Poor Asset Hierarchy and Inconsistent Data Structure
The problem. Equipment is named and structured differently at every site. The same pump type appears as four different records with four different naming conventions, and there is no consistent parent-child structure from facility down to component.
Why it costs you. You cannot compare failure rates across sites, roll up cost by asset class, or answer a simple question like “how often do these pumps fail.” ISO 14224 exists specifically because the industry needed a common taxonomy for collecting reliability and maintenance data on oil and gas equipment.4
The fix. Standardize the asset hierarchy before loading data, using a consistent taxonomy across every site. Getting this wrong is the single hardest CMMS mistake to correct later.
6. Reactive Maintenance Instead of Planned Work
The problem. The maintenance department runs on breakdowns. Work is generated by failures rather than by schedule or condition, and the backlog is whatever broke most recently.
Why it costs you. Emergency repairs cost more than planned ones, consume the crew’s capacity, and pull production down at unpredictable times. It also puts you in a poor position on mechanical integrity: 29 CFR 1910.119(j) requires inspections and tests on covered process equipment to follow recognized engineering practice and a written schedule — not to happen when something breaks.1
The fix. Build the preventive maintenance program into the CMMS on time, usage or condition triggers, and measure the ratio of planned to unplanned work as a KPI.
7. Weak Spare Parts and Inventory Control
The problem. Inventory is tracked separately from maintenance, or not tracked at all. Nobody knows whether the critical spare is on the shelf until the equipment is already down and someone goes to look.
Why it costs you. Downtime extends while parts are sourced, and emergency procurement costs a multiple of planned purchasing. In remote field operations the delay is longer still, because the part has to physically get there.
The fix. Link spare parts inventory to work order management so parts consumption is recorded against the job, reorder points reflect real usage, and criticality drives what you stock.
What a CMMS Handles in an Oil and Gas Operation
Fixing the seven mistakes above comes down to putting the whole maintenance workflow in one system rather than several. In practice that means:
- Work orders tracked from request through close-out across every site
- Preventive maintenance scheduled on time, usage or condition triggers
- Asset registers and complete equipment history under a consistent hierarchy
- Lockout/tagout procedures and inspection records attached to the work that required them
- Spare parts inventory linked to work orders, with consumption recorded against the job
- Mobile access so field technicians log work at the asset rather than back at the office
- GIS mapping for pipeline corridors and distributed field assets
- Reporting and KPIs built around planned-versus-unplanned work, downtime and cost
More detail on each of these is in the oil and gas asset management guide and the complete CMMS guide.
Frequently Asked Questions
What are the most common CMMS mistakes in oil and gas maintenance?
The most common are managing maintenance in spreadsheets instead of a single system, leaving field technicians without mobile access, tracking lockout/tagout compliance on paper, failing to connect SCADA and sensor data to maintenance workflows, building an inconsistent asset hierarchy, running reactive rather than planned maintenance, and managing spare parts separately from work orders.
How does a CMMS help oil and gas teams avoid these mistakes?
A CMMS centralizes work orders, preventive maintenance schedules, asset history, compliance documentation and spare parts inventory in one system. That removes the gaps between separate tools where maintenance data gets lost, and it makes the audit record a query rather than a search through binders and spreadsheets.
What OSHA standards apply to oil and gas maintenance?
Two are central. 29 CFR 1910.119, process safety management of highly hazardous chemicals, requires written mechanical integrity procedures, inspections and tests on covered process equipment. 29 CFR 1910.147, the control of hazardous energy, requires documented energy control procedures, employee training, and a periodic inspection of those procedures at least annually. Both generate documentation requirements a CMMS is well suited to hold.
What is ISO 14224 and why does it matter for maintenance data?
ISO 14224:2016 is the international standard for collecting and exchanging reliability and maintenance data for equipment in the petroleum, petrochemical and natural gas industries. It defines a common equipment taxonomy and failure data structure. If your asset hierarchy and failure coding follow it, you can compare equipment performance across sites and benchmark against industry data. If they do not, your reliability data only means something inside your own plant.
Why does asset hierarchy matter so much in multi-site operations?
Because every analysis depends on it. Failure rate by equipment class, maintenance cost per asset, mean time between failures, and comparisons between sites all require that the same equipment is recorded the same way everywhere. Asset hierarchy is also the hardest thing to fix after the fact, since correcting it means re-mapping every historical work order.
How does connecting SCADA data to a CMMS change maintenance?
It changes what generates a work order. Instead of a technician noticing a problem or a calendar date arriving, a condition threshold in the process data creates the work automatically. That moves the program from time-based preventive maintenance toward condition-based and predictive maintenance, where intervention is driven by the equipment’s actual state.
Sources
2. U.S. Occupational Safety and Health Administration, 29 CFR 1910.147 — The control of hazardous energy (lockout/tagout).
3. National Institute of Standards and Technology, NIST SP 800-82 Rev. 3, Guide to Operational Technology (OT) Security, September 2023.
4. International Organization for Standardization, ISO 14224:2016 — Petroleum, petrochemical and natural gas industries: Collection and exchange of reliability and maintenance data for equipment.
