Precision Lubrication

Protecting Lubricants in Standby and Intermittent Service

Greg Livingstone — Sun, 14 Jun 2026 08:00:55 +0000

Upcoming training

Machinery Lubrication Level I — Pewaukee, WI

Four days of intensive training on industrial lubrication best practices — lubricant selection, storage, filtration, and application. Built for those pursuing MLT I / MLA I certification.

July 13 – 16, 2026 · Trico Corporation, Pewaukee, WI · $1,795

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Supply chain disruption, demand volatility, and grid-balancing requirements have changed how critical rotating equipment operates. Assets that ran continuously a decade ago now sit in standby for weeks at a time. Gas turbines that once carried base load now run as peakers. Spare compressors at petrochemical sites are kept warm but rarely loaded. Seal oil systems on idle FPSO trains and standby pumps continue to circulate through coolers, bearings, and seals on weekly or monthly cycles.

The asset is available. The lubricant, however, is operating in a regime it was never formulated for.

This shift has exposed a gap in conventional thinking about lubricant management. Reliability teams know how to manage continuous service. They know how to lay up an asset for long-term storage. The middle ground — where the asset cycles intermittently, and the oil circulates through the full system on each run — is where most operators are losing ground. Antioxidants deplete faster than expected. Varnish appears in systems that had clean oil six months earlier. Bearing temperatures creep up. Servo valves stick on the first start after a long idle period.

The root cause is not the equipment or the oil, but the operating profile. The systems we are addressing share a specific duty cycle: equipment sits in standby and runs once per week or once per month. During each run, oil circulates through the complete system — pipes, coolers, gears, bearings, and seal faces. The strategy applies to both lube oil and seal oil systems on turbines, compressors, and gearboxes.

This is not layup. It is intermittent duty with extended idle periods between runs. The distinction is important because the lubricant management strategy that works for one will fail for the other.

Standby Is Often Harder on Oil Than Continuous Service

Two mechanisms work against the lubricant during intermittent operation.

1. Thermal Cycling Drops Varnish Precursors Out of Solution

Modern Group II turbine oils have lower solvency for oxidation byproducts than the Group I oils they replaced. The transition point where varnish becomes insoluble sits between 40–50°C. A continuous operating system stays above that threshold and keeps soft contaminants dissolved. A system that cycles weekly spends most of its time below 40°C, and every cooling cycle gives varnish precursors an opportunity to precipitate onto cooler tubes, servo valve spools, bearing pads, and gear meshes.

The trade literature on peak-load combustion turbines documents this clearly. The repeated heating-cooling cycle is the single most aggressive condition a turbine oil encounters, and it is more damaging than continuous high-temperature operation.

Surface-Accumulated Contamination Drives Accelerated Depletion at Each Startup

During extended idle periods, water, oxidation products, and varnish precursors accumulate on bearing surfaces, gear meshes, cooler tubes, and servo valve internals. When the system fires up, fresh oil contacts these contaminated surfaces and the antioxidant package is consumed locally and rapidly to neutralize what has accumulated. Each run cycle therefore depletes additives at a rate that exceeds what the running hours alone would predict — and the depletion is concentrated at the most critical surfaces in the system.

2. Water and Air Ingress Accumulate During Idle Periods

Breather flow, seal leakage, and condensation from ambient temperature swings introduce moisture and oxygen at rates that continuous operation would purge. Hydrolysis and oxidation continue at low rates even when the unit is not running. Over weeks and months, these reactions consume antioxidants — and degradation accelerates each time a unit is fired with moisture in the lubricant.

The combined effect of these two mechanisms is that an oil rated for 5 to 10 years of continuous service can produce varnish in 2 to 3 years of intermittent service — and the operator often does not see it coming because the standard oil analysis program was designed for a different duty cycle.

The Reason Preservative Oils Fall Short

Preservative oil formulations (MIL-PRF-3150 and MIL-PRF-16173) are engineered for static layup. They form a thin protective film on metal surfaces that displaces water and inhibits corrosion. When equipment sits motionless, the film stays where it is needed.

Circulation, however, defeats the formulation design.

The moment a preservative-charged system runs through its weekly or monthly cycle, the protective film strips from the surfaces it was meant to protect. Cutback solvents in the formulation flash off unevenly through breathers and seal points. The charge becomes a contaminated fluid that no longer functions as either a preservative or a service oil. Returning the asset to operational service requires flushing the system, refilling with the correct lubricant, and absorbing the cost and downtime of a fluid changeover on every cycle.

The compatibility problems are equally serious. Preservative oils are not formulated to coexist with the additive packages in turbine, compressor, and gearbox oils. Mixing them introduces seal compatibility risks — particularly in dry gas seal support systems and elastomer-sealed gearboxes. The cutback solvents in some formulations cause swelling in nitrile and fluorocarbon seals. The polar additives that give preservative oils their water-displacement properties can interfere with demulsibility and air release in service oils.

TOPP Test Evidence: What Contamination from Preservative Oil Actually Does

To further assess compatibility, 5% of a commonly used preservative oil was mixed with new turbine oil and stressed in an accelerated oxidation test — the TOPP Test (Turbine Oil Performance Prediction). Fig. 1 shows the visual results of this test, clearly demonstrating that a small amount of residual preservative oil will dramatically degrade turbine oil, resulting in considerable varnish formation on the MPC patch, catalyst coil, and glassware — clearly visible after just six weeks of accelerated stress.

Figure 1: The impact of 5% preservative oil mixed into a premium turbine oil after 6 weeks of accelerated oxidation. The degree of varnish formation on the MPC patch, catalyst coil, and glassware is extreme.

About the TOPP Test

The Turbine Oil Performance Prediction (TOPP) test subjects a turbine oil sample to accelerated oxidative stress at 120°C alongside an iron-copper catalyst couple, with dry air continuously bubbled through the fluid. Samples are withdrawn at 3, 6, 9, and 12 weeks and subjected to a comprehensive analytical panel tracking oxidative degradation, antioxidant depletion, acid formation, viscosity change, and deposit precursor accumulation — producing a time-resolved degradation fingerprint that reveals not just how a fluid fails, but when and why.

For systems that genuinely sit static for months or years, preservative oils are the right answer. For systems that circulate weekly or monthly, they are the wrong tool.

The Better Approach is to Maintain the In-Service Charge

The technically and economically superior strategy for circulating standby systems is to maintain the in-service charge in a condition that supports both operating and idle periods. This requires three things to work together:

Antioxidant Replenishment

The in-service oil must have its antioxidants restored before depletion reaches the point where varnish forms. Replenishment chemistry is matched to the specific in-service oil and added at concentrations that bring RULER values back into healthy ranges without disturbing the rest of the additive package.

Solvency Enhancement for Deposit Control

Replenishing antioxidants prevents future varnish, but does not address degradation products already in solution from previous thermal cycles. A formulation that increases the oil’s solvency for oxidation byproducts keeps these molecules dissolved during idle periods rather than allowing them to precipitate onto critical surfaces. Hansen solubility parameters provide the engineering basis for this approach — the objective is to extend the temperature range over which varnish precursors remain in solution, so that the heating-cooling cycle no longer drives deposition.

Single-Charge Operation

When the in-service oil is properly maintained, no separate preservative is needed. The same fluid that runs through the bearings during the weekly operational cycle protects the system during the idle period between runs. There is no flush, no changeover, and no compatibility risk on return to service.

Application Note

Fluitec’s DECON AO is engineered for this application. It combines tailored antioxidant replenishment with Solvancer technology — a patented solubility-enhancing chemistry that keeps degradation byproducts in solution and prevents adhesion to system surfaces. The product is blended on site at treat rates between 3 and 5 percent, with no special equipment required. Compatibility is confirmed through customized simulation testing on the actual in-service oil before treatment, which removes the technical risk that has historically discouraged operators from considering additive-based approaches.

For seal oil systems specifically, the same chemistry applies. DECON AO does not adversely affect elastomer compatibility, and the solvency enhancement protects servo valves, dry gas seal support equipment, and other tight-clearance components that are vulnerable to varnish during idle periods.

Recommended Monitoring Protocol for Standby Assets

A monitoring program designed for continuous service will not detect the degradation patterns that develop during intermittent operation. The following protocol is calibrated for assets that run weekly to monthly with extended idle periods between runs.

Baseline — Before Entering Standby Duty

Establish a complete reference set when the asset transitions from continuous to intermittent service. Include:

RULER — individual antioxidant species baseline
MPC — varnish potential baseline
RPVOT — bulk oxidation resistance
Karl Fischer — water content
Particle count — system cleanliness (ISO 4406)
TAN — acid number reference

This baseline becomes the reference against which all subsequent samples are evaluated.

Sampling Cadence — Tied to Circulation Cycles, Not the Calendar

Sample after each operational run, not on a fixed calendar. The oil sees its highest stress during the run itself — when the system reaches operating temperature and circulation distributes any accumulated contamination. Sampling immediately after the run captures the worst-case condition.

Triangulate RULER, MPC, and RPVOT

No single test is sufficient for intermittent-service assets:

RULER reveals additive depletion patterns before bulk oxidation resistance falls
MPC captures varnish potential earlier than visual inspection of system components
RPVOT confirms that the bulk oil retains oxidation resistance

The three tests together provide a complete picture. Using any one in isolation misses the failure modes the others detect.

Action Trigger Points

RULER — aminic antioxidants	Below 50% of baseline — action required. Below 25% — oil condemned.
MPC value	Above 15 — call to action.

Documentation for Warranty and Insurance Compliance

OEM warranty terms and insurance underwriting increasingly reference oil condition as part of the operational envelope. A documented monitoring program with quarterly sampling, RULER trending, and MPC tracking provides the evidence base that supports both warranty claims and insurance renewals. For standby assets, this documentation is often more valuable than for continuously operated equipment — because operating hours alone do not demonstrate the asset has been properly maintained.

Case Examples

Salt River Project — Mesquite Power, Arizona

Peaking gas turbine facility, grid-demand cycling

Mesquite Power, a peaking gas turbine facility operated by Salt River Project, presents the operating profile that defines this paper. The units cycle in response to grid demand, with extended idle periods between runs. DECON AO has been deployed at Mesquite as part of a proactive lubricant management strategy that maintains the in-service charge in operational readiness through repeated thermal cycles.

MPC values have been held in single digits across the treated units — well below the action threshold and consistent with oil that is genuinely ready to run rather than merely available to start. The site has become a reference case for the single-charge approach to standby asset management, demonstrating that intermittent duty does not require either accelerated oil changes or separate preservative strategies when the in-service charge is properly maintained.

Six Gas Turbines — Power Plant, Qatar

7-year-old in-service oils, varnish problem, high antioxidant depletion rate

A power plant in Qatar sought support from Petrotec Services and Rentals to identify a solution that could restore the antioxidant properties of the 7-year-old in-service turbine oils, extend their operational life, and enhance machine reliability. Historical oil analysis conducted tri-monthly with full-spectrum testing showed high varnish levels and rapid depletion of amine antioxidants and RPVOT levels — falling below 50% compared to fresh oil — raising significant concerns about equipment reliability and performance.

Fluitec’s Vita ESP III system and DECON AO were used to mitigate and maintain varnish potential within acceptable levels, restore antioxidant and RPVOT levels, and reduce the risk of six turbines shutting down with a consequent costly 120,000L oil replacement.

The above cases share a common pattern: replenishment with antioxidant restoration and solvency enhancement resolved the problem without a fluid change. The same charge continued to serve both operational and standby roles.

Figure 2: Vanda Franco working with customers in the field in Qatar.

Operational Recommendation

For turbines, compressors, and gearboxes operating in intermittent service with weekly to monthly run cycles, the engineering case is clear.

The Single-Charge Strategy — Four Commitments

Maintain the in-service charge with antioxidant replenishment and solvency-enhanced deposit control.

Avoid preservative oil approaches for any system that circulates during idle periods.

Establish a triangulated monitoring protocol tied to circulation cycles rather than calendar intervals — use RULER, MPC, and RPVOT together rather than relying on any single test.

Document oil condition systematically to support OEM warranty compliance and insurance underwriting.

The single-charge strategy reduces changeover cost, eliminates the flush requirements that come with preservative oil approaches, and produces a verifiable oil health record that supports both operational readiness and warranty compliance. For assets where the cost of an unplanned start failure exceeds the cost of the lubricant program by orders of magnitude, this is the strategy that aligns lubricant chemistry with the actual duty cycle the equipment now sees.

The supply chain crisis that pushed many of these assets into intermittent service is not temporary. It is the new operational baseline. The lubricant management strategy needs to match.

The post Protecting Lubricants in Standby and Intermittent Service appeared first on Precision Lubrication.

What Advanced Grease Tests Actually Tell You and How to Use Them

Bryan Debshaw — Sun, 14 Jun 2026 08:00:51 +0000

Upcoming training

Machinery Lubrication Level I — Pewaukee, WI

Four days of intensive training on industrial lubrication best practices — lubricant selection, storage, filtration, and application. Built for those pursuing MLT I / MLA I certification.

July 13 – 16, 2026 · Trico Corporation, Pewaukee, WI · $1,795

Reserve my spot →

For many manufacturing facilities, grease analysis stops at appearance, consistency, or contamination checks. While these basic indicators are valuable, they often fail to explain why a grease-lubricated component is degrading — or how close it may be to failure. As reliability programs mature, advanced grease analysis techniques provide deeper insight into grease health, additive condition, and wear mechanisms that basic testing often falls short on.

Advanced grease analysis techniques provide deeper insight into grease health, additive condition, and wear mechanisms — helping reliability teams move from reactive decisions to confident, condition-based action.

Why Grease Requires a Different Analytical Approach

Unlike oil, grease is a semi-solid lubricant composed of base oil, thickener, and additives. Each of these components ages differently under heat, load, contamination, and mechanical stress. Changes in grease performance are often driven by chemical degradation and mechanical breakdown long before obvious visual changes occur.

Advanced testing focuses on separating and evaluating the degradation mechanisms of base oil, thickener, and additives independently — so maintenance teams can move from reactive decisions to informed, condition-based actions.

FTIR: Understanding Chemical Degradation

Figure 1: FTIR Full Spectrum Scan example.

Fourier Transform Infrared Spectroscopy (FTIR) is one of the most valuable advanced tools in grease analysis. An FTIR Full Spectrum Scan detects chemical changes in the grease’s base oil and additives, including oxidation, nitration, and contamination from process chemicals or cleaners.

In manufacturing and processing environments, FTIR can reveal early oxidation caused by elevated temperatures or washdown conditions — often before grease hardening or bearing noise occurs.

The Key Value of FTIR Is Trend-Based Interpretation

A single data point provides limited insight, but trending oxidation and additive depletion over time allows maintenance teams to predict remaining grease life and optimize regreasing intervals. A single spectrum tells you what is there. The trend tells you where it is going.

LSV by RULER: Measuring Antioxidant Depletion

Remaining Useful Life Evaluation Routine (RULER) testing uses Linear Sweep Voltammetry (LSV) to measure the depletion of antioxidants in grease. While FTIR indicates that oxidation is occurring, RULER shows how much chemical protection remains to resist further degradation.

This technique is particularly useful in high-temperature or high-load applications common in primary metals and petrochemical facilities. As antioxidants are consumed, oxidation accelerates rapidly.

The Inflection Point RULER Identifies

RULER data helps identify the inflection point where grease condition can deteriorate quickly — often well before mechanical symptoms appear. Once antioxidants are depleted, the remaining service life collapses rapidly. RULER is the only test that provides advance warning of this transition.

FTIR and RULER answer different questions. FTIR tells you that oxidation is occurring. RULER tells you how much capacity remains to resist it. Used together, they define both where the grease is and how far it has left to go.

Water Measurement, Microbial Growth, and Wear Debris Analysis

Figure 2: Water and microbial contamination analysis example.

Advanced testing can measure water content, microbial growth, and wear to provide deeper insight into contamination, degradation drivers, and internal wear conditions. Water contamination is a leading cause of grease failure, contributing to oxidation, additive depletion, and corrosion.

Water by Crackle — Qualitative Screening

Serves as a rapid screening tool that quickly confirms the presence of free or emulsified water during condition checks or when suspected ingress is present. It is qualitative, not quantitative, and cannot determine moisture concentration — but it is fast and practical at the point of collection.

Water by Karl Fischer — Quantitative Precision

Provides highly accurate, quantitative measurement of both free and dissolved water, enabling detection of low moisture levels that can still accelerate oxidation and shorten grease life. When trended alongside FTIR and RULER data, Karl Fischer results often reveal cause-and-effect relationships such as moisture-driven oxidation or accelerated additive loss.

ATP Testing — Microbial Activity Detection

Identifies microbial activity within grease. In wet or contamination-prone environments, microbial growth can degrade grease structure, generate corrosive byproducts, and accelerate lubricant breakdown. Detecting ATP content early helps confirm biological contamination as a contributing factor and identify root causes that water analysis alone would not reveal.

Ferrous Debris Monitoring (FDM) — Wear Mode Identification

Performed by the FerroQ test method, FDM helps identify active wear modes within components. Large or abnormal particles may indicate surface fatigue, misalignment, or contamination-induced damage. In heavily loaded or slow-speed applications, this analysis helps determine what is contributing to grease degradation — providing the mechanical dimension that chemical tests alone cannot supply. This is the link between lubricant chemistry and component condition.

Choosing the Right Tests and Avoiding Over-Testing

Figure 3: Test selection matrix by asset criticality and operating conditions.

One of the most common mistakes with advanced grease testing is applying every available test to every asset. Not all techniques deliver value in every application. A best practice for grease reliability testing is to select tests based on asset criticality, operating conditions, and known failure modes.

Over-Testing Is a Real Cost — And It Obscures What Matters

Applying the full test panel to every asset generates data volume without insight. The result is analysis paralysis, report fatigue, and missed signals on the assets that actually matter. The discipline is not in running more tests — it is in running the right tests on the right assets, consistently.

Matching Tests to Asset Profile

High-temperature or chemically aggressive environments — FTIR and RULER are the priority. They track the degradation mechanisms that elevated temperature drives fastest.

Critical bearings with known wear risks — add Ferrous Debris Monitoring to track mechanical degradation alongside chemical condition.

Wet or contamination-prone environments — Karl Fischer and ATP testing provide the moisture and microbial dimensions that FTIR alone will not quantify.

Low-criticality assets — routine consistency and contamination checks may be entirely sufficient. Not every asset earns advanced testing.

Sampling Quality Determines Data Quality

Generating reliable trending data depends on collecting consistent, repeatable, and truly representative grease samples. Inconsistent sampling methods or locations introduce variability that reduces the accuracy and value of results. Most laboratories provide specialized grease sampling kits and standardized instructions designed to ensure samples reflect in-service conditions. The integrity of the sample governs the integrity of every result that follows.

Turning Advanced Data into Reliability Gains

Advanced grease analysis techniques provide a clearer picture of grease health, remaining useful life, and emerging failure mechanisms. When applied selectively and interpreted in context, these tools help reliability teams optimize intervals, prevent premature bearing failures, and make confident maintenance decisions.

A Question Worth Asking Your Program

Is your current grease analysis program telling you what is happening inside the grease — or only confirming what you can already see from the outside?

Moving beyond basic testing is not about complexity — it is about understanding what matters most inside the grease that protects your most critical assets.

The post What Advanced Grease Tests Actually Tell You and How to Use Them appeared first on Precision Lubrication.

Why Asset Failures Often Start in the Lube Room

Sanya Mathura — Sun, 14 Jun 2026 08:00:47 +0000

Upcoming training

Machinery Lubrication Level I — Pewaukee, WI

Four days of intensive training on industrial lubrication best practices — lubricant selection, storage, filtration, and application. Built for those pursuing MLT I / MLA I certification.

July 13 – 16, 2026 · Trico Corporation, Pewaukee, WI · $1,795

Reserve my spot →

When we think about the lube room, there can be a few images which come to mind. Either a pristine environment, with everything colour coded, neatly packed on the assigned shelves, dedicated storage and handling containers and a temperature-controlled environment (everyone’s dream!). Or we can have a mix of dirty, oily rags, creatively designed dispensing containers where the welders were definitely showing off their skills and mislabeled (or no labels) on the lubricants. We can also have many images in between since there is a range of things which can be done (or not done) by those in charge of the lube rooms given their environmental conditions and constraints (budgetary or operational).

Unfortunately, the lube room is the place where many failures can begin if the conditions are not appropriate. It should ideally be the first line of defense for our assets but is often overlooked. Typically, this is the starting point of the journey for any lubricant and if it carries contaminants then we are exponentially decreasing the life of our lubricated assets before they have a chance to operate in our facility. This article explores the ways in which we can reduce these effects and some areas of improvement for any lube room.

Addressing Contamination

The ISO 4406 test is one that the industry is very familiar with as it governs the cleanliness of the oil. Typically, every system / OEM has a targeted cleanliness level. But how does the cleanliness level actually impact the lubricant and its functions? It is often said that the industry runs on a film of oil that is between 1–10 microns. Essentially, that means that any particle which is larger than this range interrupts the film and can cause damage and wear to the components.

For those not familiar with ISO 4406, this quantifies the number of particles into three categories, ≥4μm / ≥6μm / ≥14μm particles per milliliter of fluid. Each category measures the quantity of particles that fit the size bracket and then these are translated to a scaled number. As such, the numbers represented are not the actual quantity of the particles of that size.

Table 1: ISO 4406 Rating Scale

More than	Up to and including	Scale Number
2,500,000	—	>28
1,300,000	2,500,000	28
640,000	1,300,000	27
320,000	640,000	26
160,000	320,000	25
80,000	160,000	24
40,000	80,000	23
20,000	40,000	22
10,000	20,000	21
5,000	10,000	20
2,500	5,000	19
1,300	2,500	18
640	1,300	17
320	640	16
160	320	15
80	160	14
40	80	13
20	40	12
10	20	11
5	10	10
2.5	5	9
1.3	2.5	8
0.64	1.3	7
0.32	0.64	6
0.16	0.32	5
0.08	0.16	4
0.04	0.08	3
0.02	0.04	2
0.01	0.02	1
0.00	0.01	0

Table 1: ISO 4406 rating scale.

Therefore, an ISO code of 20/15/13 represents:

20	between 5,000 – 10,000 particles larger than 4μm in one milliliter of fluid
15	between 160 – 320 particles larger than 6μm in one milliliter of fluid
13	between 40 – 80 particles larger than 14μm in one milliliter of fluid

New oil delivery in container sizes between a pail or a truck load, the cleanliness value can be excellent. Sometimes these values can be as clean as ISO 16/14/11, but can also be quite poor. A 16/14/11 score is great, but perhaps our turbines or hydraulic systems particularly those with EHC systems require something more stringent (due to their tighter clearances) such as ISO 14/12/9. The table below shows a comparison of what that actually means as it relates to the number of particles in the oil for these ratings.

Table 2: New Oil vs. Turbine Oil Specifications

Particle Size	New Oil — ISO 16/14/11	EHC System Spec — ISO 14/12/9
>4μm	320 – 640 per mL	80 – 160 per mL
>6μm	80 – 160 per mL	20 – 40 per mL
>14μm	10 – 20 per mL	2.5 – 5 per mL

Table 2: Comparing new oil to Turbine oil specifications for EHC systems.

As we see in Table 2, there is a major difference between the number of particles at the 4 micron level between what is being delivered to the facility as new oil versus what the turbine actually requires. When we translate that to the fact that bearings in turbines may run on a film of oil which is between 1–10 microns, and our new oil has potentially 640 particles that are bigger than 4 microns, then we can conceptualize that the oil film will most definitely be disrupted!

This ISO cleanliness level starts off from the entry of the “clean” lubricant into the plant. If we factor in drums which have been exposed to the atmosphere, dirty transfer containers which already contain contaminants or bad practices (leaving hoses open to the atmosphere), then the ISO contaminant ratings will significantly increase. This means we are literally pouring contaminants into our oils and our assets.

Thus far, we have only described the contaminants in the form of solid particles, but contaminants can also exist in the liquid form (fuel, water, other lubricants, process liquids) or gaseous form (air, process gases). These can all affect the lubricant either acting as catalysts or fouling the system.

The Unseen Failure Chain

When we think about starting from the lube room and tracing the chain of events which leads to failure, it will look similar to Figure 1 below.

Lubricant stored incorrectly

Drum left open or unsealed; exposed to humidity, temperature swings, or airborne particulates

Contamination enters the oil

Particle or moisture contamination accumulates undetected since there are no incoming cleanliness checks in place

Contaminated oil dispensed into the machine

Transfer equipment is dirty; no filtration applied during top-up or oil change

Lubricant film integrity compromised

Particles damage surfaces; water depletes antioxidants and anti-wear additives; viscosity increases or decreases accordingly

Premature asset failure

Bearing, pump, or gearbox fails ahead of design life and the physical root cause attributed to the machine, not the lube room

Figure 1: Chain of failure events.

In this case, contaminants start off in the lube room, and they enter the equipment, wreak havoc and then lead to failure. During many failure investigations, the analyst stops at the physical root causes and can easily blame the component. Since they did not investigate further, they missed that the source of contamination actually came from the lube room and possibly bad storage and handling practices.

Mislabeling and Environmental Conditions

Thus far, we’ve spoken about the effects of mainly physical contamination but quite a number of things also happen in the lube room. One major aspect of compromise is proper labelling of the lubricants. Many times, technicians are in a rush to get their lube route underway and will often not double check that they have the correct lubricant for the application that they are working on. In these cases, they may have picked up the wrong lubricant which is not the appropriate viscosity or suited for the application either!

This can lead to incompatible lubricants being mixed causing a series of failures. It can also lead to incorrect viscosity being applied to the equipment causing wear and tear or efficiency losses. Additionally, if the wrong type of oil is used, this can also lead to severe bleaching of the additives out of the oil.

For instance, if a motor oil (which contains 30% additives) was placed in a hydraulic oil sump, this can lead to catastrophic events where the additives in the motor oil may trap water getting into the hydraulic oil making it emulsify rather than allowing the water to drop out.

As such, we need to ensure that there are adequate labeling systems in place to minimize the occurrence of a mix up with the lubricants. Colour coding can also help as this reduces the errors of “picking up” the wrong dispensing container especially when our technicians are in a hurry.

The environment has a huge role to play regarding the integrity of lubricants. If lubricants are stored outside in drums, they have the tendency to collect rainwater. They can breathe and draw in this rainwater which gets collected at the top of the drum. This breathing action occurs due to changes in temperature such as the change from a bright sunny environment to a rainstorm. This introduces water into the oil and contaminates it before it reaches the equipment. Lubricants should be stored at controlled temperatures between 0–25°C and in a sheltered area.

The Ideal Lube Room

While many may think it is costly or impossible to transform their current lube room, there are a few low-cost adjustments which can be made to help reduce the initiation of failure in this area. As shown in Figure 2, these small changes can have big impacts on reducing the contaminants which get into the oils before they are added to the machines.

Incoming lubricant verification

Test new deliveries against the certificate of analysis and, where critical equipment is involved, perform an incoming cleanliness check before the oil enters storage.

Sealed storage with desiccant breathers

All drums and totes should be sealed when not in use. Desiccant breathers on storage containers and transfer vessels prevent moisture ingress during thermal breathing cycles.

Colour-coded and labelled systems

Every container, every dispenser, every grease gun should carry the same colour code and label as the lubricant it contains and that code should match what is posted on the machine.

Dedicated dispensing equipment

Avoid shared transfer containers between lubricant types. Dedicated equipment eliminates cross-contamination risk and simplifies auditing.

Kidney loop filtration at point of use

Where the required cleanliness target exceeds what the stored oil can provide, kidney loop or transfer filtration brings the oil to target before it reaches the machine.

Environmental controls

Manage temperature and humidity in the lube room. In hot, humid climates, even partial climate control such as a wall-mounted air conditioner, adequate ventilation, thermal insulation on the roof can meaningfully extend the storage life of lubricants.

FIFO stock rotation and shelf life tracking

Every lubricant has a recommended shelf life. A simple tagging system that records receipt date and flags stock approaching its limit prevents degraded oil from reaching machines.

Figure 2: Strategies for an Ideal Lube Room.

By implementing some of the aforementioned strategies, we can see an immediate reduction in the number of failures which occur at a facility. While many think about investing in predictive technologies which may range to the higher cost bracket, these simple adjustments to the lube room can easily solve a large percentage of the issues.

If we were to think about this in terms of the cost of the failures for gearboxes or other critical pieces of equipment, the investment in these strategies to upgrade your lube room is minimal. When investigating your next failure, perform a full root cause analysis and determine whether it’s stemming from your lube room. Chances are that you have the opportunity to prevent a lot more failures than you would expect.

The post Why Asset Failures Often Start in the Lube Room appeared first on Precision Lubrication.

FTIR in Compressor Oils: From Routine Monitoring to High Value-Added Diagnostics

Jorge Alarcon — Sun, 14 Jun 2026 08:00:35 +0000

Upcoming training

Machinery Lubrication Level I — Pewaukee, WI

Four days of intensive training on industrial lubrication best practices — lubricant selection, storage, filtration, and application. Built for those pursuing MLT I / MLA I certification.

July 13 – 16, 2026 · Trico Corporation, Pewaukee, WI · $1,795

Reserve my spot →

In a compressor oil, comparing a new sample with samples in service allows the progressive appearance of oxidation and thermal degradation byproducts to be monitored. This reference methodology is especially useful because each formulation has its own spectral fingerprint — what matters is not only the absolute spectrum but also the change from the original base oil, measured in the oil’s areas and peaks.

Comparing the new sample with used samples makes it easier to detect variations in bands associated with oxygenated functional groups. In the mid-infrared carbonyl region, an increase in absorbance typically reflects the formation of aldehydes, ketones, esters, and carboxylic acids — all related to lubricant oxidation.

This approach allows interpretation of whether the oil is in an early, intermediate, or advanced phase of aging — providing actionable insight at each stage rather than waiting for a functional failure to confirm what the chemistry already knew.

Early Oxidation of the Oil and Evidence of Thermal Degradation

One of the great strengths of FTIR is its ability to detect oxidation early — before the oil reaches a clearly out-of-service state. In compressor oils, this is critical because elevated temperature favors the formation of intermediate species that are then transformed into more aggressive compounds for the system.

Oxidative degradation usually begins with radicals and intermediates that ultimately form aldehydes and ketones. These species can be observed indirectly as changes in the carbonyl zone of the spectrum. Over time, some of these products evolve into carboxylic acids, which increase the oil’s acidity and accelerate corrosion, autocatalytic oxidation, and deposit formation.

Thermal Degradation: The Dimension Standard Labs Often Miss

In compressors with high discharge temperatures, FTIR can detect thermal degradation, not just oxidative. The appearance of byproducts such as lactones is especially relevant — they are associated with advanced thermal degradation pathways and the transformation of oxidized compounds into more complex cyclic structures. A laboratory that reports only an oxidation value from FTIR is discarding this dimension entirely.

The advantage of a reference spectrum is that any increase or modification in the bands is more clearly appreciated. If later samples exhibit more intense behavior than the initial ones, it suggests progression of thermal-oxidative aging. In other words, FTIR not only indicates that the oil has changed — it helps understand how it is changing.

What makes FTIR a truly diagnostic tool is the comparison with a reference sample. A single spectrum tells you what is there. The differential tells you what has changed — and at what rate. The trend is the diagnosis.

Two Compressor Case Study

Two compressors at the same facility. Identical operating conditions. Two very different analytical outcomes — because of how their FTIR data was used.

Compressor 1 — Conventional FTIR Approach

Oxidation-only reporting; problem detected only at failure

Samples from this compressor were sent to an oil analysis laboratory that performed complete analysis using FTIR, but limited to identifying oxidation only. The laboratory could not detect the developing problem — until unplanned stops occurred due to an increase in oil temperature, filter clogging, and the presence of varnishes.

The failure was not the compressor’s. It was the analytical model’s. By the time the standard FTIR reported an oxidation value that warranted concern, the damage was already underway. This case is presented not as an example of poor maintenance, but as a demonstration of what a narrow analytical scope costs in practice.

Compressor 2 — Full-Spectrum FTIR with OilMirror

Four service samples + reference oil; multi-band differential analysis

This compressor was monitored by a laboratory applying a properly adequate FTIR analysis, taking full advantage of the analytical technique. Four service samples were analyzed in addition to the reference oil, providing a longitudinal view of the oil’s chemical evolution.

Sample 1 reflects an early phase of service, where small variations begin to appear due to initial oxidation. Samples 2 and 3 show greater accumulation of oxidation products, with increased carbonyl-associated bands and changes in other functional areas. Sample 4 represents the most advanced stage, where clearer signals of oxidation, thermal degradation, and the potential appearance of more complex byproducts are observed.

This trend reading is more useful than a one-off interpretation of a single sample — lubricant degradation is a progressive process, and FTIR allows us to observe it as a chemical film of the oil’s aging.

Figure 1: FTIR spectra overlay — all service samples vs. reference oil (OILMIRROR)

Figure 2: Trend of most drastic spectral changes across service samples (OILMIRROR)

Advanced Analysis Using OilMirror

About OilMirror

OilMirror, developed in 2024, applies advanced infrared spectral analysis across the full IR band to detect anomalies and reaction products that alter a lubricant’s chemical composition. It translates this complexity into an intuitive global health index, or a set of focused indicators tailored to specific spectral regions. Designed for asset owners, consultants, and reliability teams, OilMirror empowers lubricant end-users with deep, lab-grade insights — without requiring laboratory expertise.

The FTIR data from the second compressor was uploaded to the OilMirror tool, which analyzes spectra and issues partial results for each FTIR area and peak, as well as a global oil status and a series of recommendations for the compressor maintenance team.

Figure 3: Per-area and per-peak evaluation scores across service samples (OILMIRROR)

Figure 4: Global Condition dashboard output (OILMIRROR)

Value for Predictive Maintenance

In industrial compressors, detecting oil degradation in time has a direct impact on equipment reliability. An oil that begins to degrade can lose lubricating capacity, generate deposits in valves and hot areas, and accelerate wear on critical components. FTIR should therefore be treated as a predictive maintenance tool — not a laboratory control metric that gets filed away after the report is received.

FTIR + Viscosity + TAN

Combined with viscosity and TAN measurements, FTIR provides the chemical dimension of the problem — distinguishing simple oil aging from an active degradation mechanism that requires intervention.

FTIR + Particle Counting

Particle counting identifies wear debris and solid contamination; FTIR identifies the chemical degradation that generates it. Together, they show both what is happening mechanically and why it is happening chemically.

FTIR + Wear Analysis

Wear metals tell you where the compressor is being damaged. FTIR tells you whether the lubricant chemistry is the cause or a contributing factor. The combination enables root-cause analysis — not just problem detection. This is the difference between reactive and predictive maintenance.

The Differential Methodology: Why the Reference Sample Is Non-Negotiable

FTIR without a reference sample is like reviewing a patient’s lab results without a baseline. A single spectrum tells you what compounds are present — but it cannot tell you whether they are increasing, stable, or appearing for the first time. The reference sample is what transforms FTIR from a measurement into a diagnostic tool. Without it, you are reporting; with it, you are monitoring.

Some Final Comments

FTIR applied to industrial oils is a valuable technique for anticipating lubricant degradation. Its ability to identify the formation of aldehydes, ketones, and other oxidation byproducts early — before they evolve into carboxylic acids — is what makes it genuinely predictive rather than merely confirmatory.

The differential methodology also facilitates the detection of signals compatible with lactones and other compounds derived from thermal degradation, which significantly expands the diagnostic scope of the analysis beyond what oxidation value alone can capture.

In air and gas compressors, where thermal and oxidative stress is high, this ability to anticipate is decisive for planning oil changes, avoiding premature failures, and preserving the integrity of the equipment.

FTIR Should Not Be a Confirmatory Test — It Should Be a Leading Indicator

Always analyze against a reference oil sample — the differential is the diagnosis, not the absolute spectrum.

Require full-band analysis — not just an oxidation value. Thermal degradation markers such as lactones require broader spectral coverage.

Track trends across multiple samples — a single FTIR snapshot misses the trajectory. The trend is what drives maintenance decisions.

Combine FTIR with complementary techniques — viscosity, TAN, particle counting, and wear analysis — to distinguish chemical aging from active mechanical degradation.

A Question Worth Asking Your Laboratory

Do you still work with a laboratory that only reports oxidation as a parameter of the FTIR analysis? Are you sure of its real value to your maintenance decisions?

The technology to see lubricant degradation before failure exists. The question is whether the analytical program around it is designed to use it — or merely to generate a report.

The post FTIR in Compressor Oils: From Routine Monitoring to High Value-Added Diagnostics appeared first on Precision Lubrication.

Lubrication Certifications Review The STLE Certified Lubrication Specialist™ (CLS)

Doug Sackett — Sun, 14 Jun 2026 08:00:22 +0000

Upcoming training

Machinery Lubrication Level I — Pewaukee, WI

Four days of intensive training on industrial lubrication best practices — lubricant selection, storage, filtration, and application. Built for those pursuing MLT I / MLA I certification.

July 13 – 16, 2026 · Trico Corporation, Pewaukee, WI · $1,795

Reserve my spot →

About STLE: A Legacy of Tribology

In 1944, the American Society of Lubrication Engineers (ASLE) was founded as a non-profit association to advance the knowledge and application of the science of lubrication and tribology. The society created a forum for the steel industry, enabling lubrication engineers to build a network of seasoned professionals to interact and grow. In 1987, it was renamed the Society of Tribologists and Lubrication Engineers (STLE) to better reflect its expanding scope across all areas of tribology.

What is Tribology?

Lubrication engineering relates to the reduction of friction and wear between relatively moving parts. The term tribology was coined in the mid-1960s in Great Britain to describe the study of interacting moving surfaces — derived from the Greek word “tribos” (the science of rubbing). Tribology encompasses physics, chemistry, applied mathematics, metallurgy, material science, mechanical engineering, chemical engineering, and applied mechanics.

Origins of the CLS Certification

In 1990, a group of STLE members led by Richard E. Rush, Tom Lantz, Dan McCoy, and Larry Cole formed a committee to create one of the first STLE Certified Lubrication Specialist™ (CLS) exams. The exam was designed for the applied, hands-on individual responsible for keeping industrial machinery operating — with a deliberate emphasis on practical application over theory.

Exam Format and History

The CLS exam was first administered at the 1993 STLE Annual Meeting in Calgary, Alberta. Of the 25 initial candidates, 18 achieved a passing grade. The original format was a fill-in-the-blank exam, requiring test takers to know the body of knowledge thoroughly in order to answer succinctly and accurately.

In 2011, the format shifted to a 100 (150 Question) -question multiple-choice exam — eliminating ambiguity in interpreting correct answers while covering the same 16 areas of field tribology that define the body of knowledge for a certified lubrication specialist.

Exam Integrity and Industry Standing

The validity and integrity of the CLS exam have been challenged over the years. To date, it has passed every challenge — upheld by strict guidelines handed down to all members of the STLE CLS Committee, ensuring the quality of each question and the research and documentation required to support the answers.

The CLS is considered the most extensive certification in the lubrication field and one of the most difficult to achieve. STLE has maintained a long-standing focus on certifying the best, not the masses. The program’s success has inspired other certification programs to emerge in the field — each with its own place in the growth of the lubrication world.

Pursuing the CLS: What to Expect

STLE offers a range of study resources for CLS candidates, including reference materials and recommended reading aligned to the exam’s body of knowledge, along with a curated list of exam prep partners. Connecting with other certified professionals in one’s network is also strongly encouraged — often one of the most valuable parts of the preparation process.

Eligibility is based on a combination of education and relevant work experience. Many candidates are surprised to find they already qualify before beginning formal preparation. Employers are often willing to support the investment once they understand the value it brings: greater technical competence, reduced operational risk, and stronger professional credibility.

The STLE CLS Committee currently comprises 16 subject matter experts from across the industry, continuously updating and reviewing the question bank. Once earned, the CLS designation is valid for three years and renewed through a flexible combination of professional development activities — a process recently revised to better accommodate working professionals.

Key Facts at a Glance

Committee	16 subject matter experts across all exam domains
Languages	English · German · Spanish (available July 1)
Exam Fee	$450 STLE members · $625 non-members
Validity	3 years — renewable via professional development
Learn more	www.stle.org/certifications

Table 1: CLS certification key facts.

The STLE Certification Suite

While the CLS remains the flagship credential in the lubrication world, STLE has developed a broader suite of certifications to serve the full spectrum of tribology and fluid management professionals:

Table 2: STLE Certification Suite

Credential	Full Name	Target Audience
CLS	Certified Lubrication Specialist™	Industrial lubrication professionals — the flagship credential
CMFS	Certified Metalworking Fluids Specialist™	Professionals in metalworking fluid applications
OMA	Certified Oil Monitoring Analyst	Oil analysis & condition monitoring analysts
OMX	Certified Oil Monitoring Expert	Senior practitioners in oil monitoring

Table 2: STLE’s four professional certifications.

Each credential carries its own body of knowledge, exam structure, and eligibility requirements — providing clear, recognized pathways for professionals across all areas of tribology. Together, they reflect STLE’s commitment to setting the standard for professional excellence across the industry.

A Closer Look at Each STLE Certification

All STLE certification exams are taken remotely — at home or in a private work environment — on a computer with a secure internet connection and webcam. Results are provided immediately upon completion. All certifications are valid for three years and require recertification to maintain status. Exam fees are $450 USD for STLE members and $625 USD for non-members (retake: $225/$305 respectively).

CLS — Certified Lubrication Specialist™

The flagship credential — broad lubrication engineering knowledge

The CLS is STLE’s flagship credential and the only independent certification that verifies broad lubrication engineering knowledge for industrial professionals. Recognized globally as the industry standard for technical excellence, independent studies show that CLS-certified professionals earn more, supervise larger staffs, and are more likely to receive raises. The certification is suited for professionals who evaluate and select lubricants, conduct lubrication surveys, develop quality assurance programs, troubleshoot lubrication issues, and maintain lubricant records.

The exam consists of 150 questions in 180 minutes, with a passing score of 70% or higher, and is available in English and German. Prerequisite: 3 years of relevant lubrication experience. Key exam topics include lubrication fundamentals (16%), hydraulics (8%), fluid conditioning and analysis (8%), lubrication programs and consumption (8%), problem solving (8%), grease (6%), bearings (6%), gears (6%), mobile equipment (6%), metalworking (6%), energy (6%), compressors (4%), seals (4%), lubricant manufacturing (4%), and special lubricants (4%).

CMFS — Certified Metalworking Fluids Specialist™

For metalworking fluid management professionals

The CMFS designation verifies knowledge, experience, and education in metalworking fluid management. It is designed for professionals responsible for metal-removal or forming management, application, and handling of metalworking fluids. Target roles include tech support, product application, MWF sales, formulators, product development, and sales representatives. Candidates should have foundational knowledge of fluid chemistry, machining processes, metallurgy, tooling, filtration, and waste treatment.

Prerequisites include a two-year degree in science, manufacturing technology, or business (four-year recommended), plus 20 hours of MWF training and 3 years in a manufacturing setting (or 5 years in a lab). The exam is 150 questions in 180 minutes, 70% passing threshold.

“The certification is highly regarded as an elitist accreditation within the metalworking fluids community. Passing the exam demonstrates one has the necessary training, real world experience and expertise in the field of MWF’s many uses including field analysis, troubleshooting methodology, root cause failure analysis, and refined technical support.”

— Jason Bealby, CMFS Committee Chair

OMA — Certified Oil Monitoring Analyst™

For predictive maintenance professionals overseeing oil analysis programs

The OMA certification is designed for predictive maintenance professionals who oversee oil analysis programs. It suits mechanics, engineers, operators, tradesmen, chemical managers, and on-site lab personnel responsible for oil sampling, reviewing reports, performing the correct tests, and maintaining overall equipment care. The OMA demonstrates proficiency in sampling, data interpretation, and lubricant health assessment to support proactive maintenance strategies.

Prerequisites: 16 hours of oil analysis training and 1 year of experience utilizing oil analysis in the field. The exam covers sampling, application/test methods, data interpretation, troubleshooting, and lubrication fundamentals — 150 questions in 180 minutes, 70% required to pass.

OMX — Oil Monitoring Expert

STLE’s advanced-level oil monitoring credential

The OMX is STLE’s advanced-level oil monitoring credential, recognizing professionals with advanced proficiency in lubricants, lubrication, and comprehensive oil analysis. OMX holders possess the expertise to select appropriate testing techniques, understand sophisticated instrumentation, evaluate complex results to diagnose equipment problems, perform root cause analysis, and prescribe corrective actions. Target roles include oil analysis diagnosticians, lubricant technical support, commercial laboratory technicians, and managers of oil analysis programs.

Prerequisites: 24 hours of oil analysis training and 5+ years of practical experience in oil analysis. The exam is 150 questions in 180 minutes, 70% passing threshold. Key topics include data interpretation (14%), analysis (11%), actions (9%), maintenance (9%), lubricant selection (7%), and limits & alarms (5%), among others.

“The OMX was the most challenging exam I have written among all industry certifications — it represents a proven level of expertise and diagnostic capability in oil analysis.”

— OMX Committee Member

The post Lubrication Certifications Review The STLE Certified Lubrication Specialist™ (CLS) appeared first on Precision Lubrication.

The Oil Was There—But the Bearing Still Failed

Mohammad Naseer Uddin — Sun, 14 Jun 2026 08:00:01 +0000

Upcoming training

Machinery Lubrication Level I — Pewaukee, WI

Four days of intensive training on industrial lubrication best practices — lubricant selection, storage, filtration, and application. Built for those pursuing MLT I / MLA I certification.

July 13 – 16, 2026 · Trico Corporation, Pewaukee, WI · $1,795

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In Precision Lubrication, failures are often attributed to poor oil quality or contamination, but the reality is rarely that simple. What happens when the oil is present, yet the bearing still fails?

At a remote crude oil export station in the Middle East, a critical 720 kW pump motor experienced a sudden bearing seizure, preceded only by abnormal noise and smoke. While initial inspection pointed to a failed oil ring, deeper analysis revealed a more complex picture. The incident was not caused by a single fault, but by a combination of interacting factors — most notably oil ring instability compounded by poor contamination control, sludge formation, and degraded lubricant condition.

This case highlights a critical but often overlooked reality: lubrication failures are rarely isolated — they result from system-level weaknesses acting together.

Equipment Background

The failure occurred on a 720 kW, 6.6 kV, 2980 RPM induction motor driving a crude oil export pump at a remote oil field facility.

The motor used journal bearings with oil-ring lubrication, in which a freely rotating ring lifts oil from the sump and distributes it to the bearing surface. This simple system is widely used, but highly dependent on proper operating conditions.

The Incident

During operation, the field operator observed abnormal noise followed by smoke from the drive-end bearing housing. The pump was immediately shut down to prevent escalation.

Inspection Revealed

Seized drive-end bearing
Severe journal scoring and metal smearing
Sludge deposits and degraded lubricant
A fractured oil ring
A damaged locator (guide) pin

Importantly, a similar failure had occurred on another pump approximately six months earlier — indicating a recurring reliability issue rather than an isolated event.

Figure 1: Severe scoring damage on journal bearing.

Figure 2: Sludge in the lubricant sump.

Forensic Insight: What the Broken Ring and Pin Reveal

The physical evidence provides valuable insight into the actual progression of the failure.

Oil Ring Failure

The oil ring was found broken into two halves, with clear signs of uneven wear and thermal distress.

This Indicates

Loss of stable rotation
Increased drag due to sludge and degraded oil
Progressive fatigue leading to fracture

Figure 3: Oil ring found broken.

Figure 4: Broken oil ring.

Locator Pin Damage

The locator pin, designed to maintain axial alignment of the oil ring, was also found damaged.

Critical Observation

The failure of this pin suggests that the oil ring was operating under unstable conditions, not merely experiencing normal wear.

Classic Indicators of Oil Ring Instability

Wobbling or running eccentrically
Experiencing intermittent sticking and slipping
Generating abnormal dynamic forces

Figures 5 & 6: Damaged locator pin.

Failure Mechanism: A Multi-Factor Breakdown

This was not a simple component failure — it was a system-level lubrication breakdown driven by multiple interacting factors.

Contamination and Sludge Formation

The site lacked effective oil contamination control measures. Oil storage, handling, and dispensing practices were poorly managed, resulting in ingress of dust and environmental contaminants, accelerated oil degradation, and sludge formation within the system. This altered the lubricant’s physical behavior and directly affected lubrication performance.

Figure 7: Lubricant oil drums stored outdoors.

Oil Ring Slippage

Oil rings depend on frictional engagement with the shaft to rotate. Degraded oil conditions significantly affected this mechanism — increased viscosity and tackiness reduced effective frictional grip, causing the oil ring to slip instead of rotate. This is a critical but often overlooked failure mode.

As a result:

Oil pickup efficiency reduced
Oil delivery to the bearing decreased
Hydrodynamic lubrication gradually collapsed

Progressive Mechanical Instability

As lubrication conditions worsened, a cascade of mechanical failures followed:

The oil ring became unstable and began to wobble
The locator pin was overloaded and eventually damaged
Loss of alignment introduced stress concentration
Cyclic loading led to fatigue fracture of the oil ring

Final Failure

With oil delivery effectively lost:

Bearing temperature increased rapidly
Metal-to-metal contact developed
Severe surface damage occurred
The bearing ultimately seized

Consequences

The impact of this failure extended well beyond maintenance.

Impact Summary

~USD 20,000

Maintenance Cost

~185 m³/day

Production Deferred

High

Process Safety Risk

The incident was classified as a near miss, emphasizing the direct relationship between lubrication practices, reliability, and safety. An overheated bearing in a hydrocarbon-rich environment carries consequences that go far beyond the mechanical.

Key Insight: Lubrication Is a System

This case reinforces a fundamental principle:

“The broken oil ring and damaged pin were not root cause — they were symptoms of a deeper lubrication system failure.”

Precision Lubrication depends on three critical elements working in concert:

Healthy Lubricant

Oil in good condition, properly stored, handled, and free of contaminants — before it ever enters the system.

Reliable Delivery Mechanism

Components such as oil rings and locator pins that function correctly and consistently deliver oil to bearing surfaces.

Controlled Contamination Environment

Storage, handling, and system protection practices that keep contaminants out and maintain lubricant integrity throughout its service life.

Preventive Actions

A holistic approach was recommended to prevent recurrence across similar equipment at the site.

Oil Ring Integrity

Inspect oil rings for free rotation, wear, and deformation
Replace worn rings proactively across similar equipment
Ensure correct oil level for proper ring immersion

Contamination Control

Implement sealed storage and proper dispensing systems
Use dedicated, color-coded, clean transfer containers
Install desiccant breathers and filtration systems
Define and maintain oil cleanliness targets

Oil Condition Monitoring

Monitor all critical oil parameters on a defined schedule
Conduct periodic oil analysis to detect degradation before failure

Maintenance Strategy

Include oil ring inspection in yearly maintenance cycles (Y1)
Extend inspection scope to all similar pumps at the facility

Design Improvement

Consider replacing oil rings with flinger discs or forced lubrication systems for critical applications where oil ring instability is a known risk

Conclusion

This incident serves as a powerful reminder that Precision Lubrication is not just about the lubricant — it is about the entire system that supports it.

A small oil ring operating in a contaminated, poorly controlled environment became unstable, failed, and ultimately led to a major breakdown. The damaged pin and fractured ring were simply the final evidence of a system already in distress.

In high-value operations, lubrication must be treated as a controlled and engineered process, not a routine task.

Reliability is not defined by the presence of lubricant oil —
but by its ability to consistently reach and protect the bearings.

The post The Oil Was There—But the Bearing Still Failed appeared first on Precision Lubrication.

Give it to me Straight: Are we headed to a Lube Supply Crisis?

Rich Wurzbach — Fri, 12 Jun 2026 08:00:52 +0000

Upcoming training

Machinery Lubrication Level I — Pewaukee, WI

Four days of intensive training on industrial lubrication best practices — lubricant selection, storage, filtration, and application. Built for those pursuing MLT I / MLA I certification.

July 13 – 16, 2026 · Trico Corporation, Pewaukee, WI · $1,795

Reserve my spot →

The likely answer is YES, it is highly likely that lubricant shortages are once again right around the corner!!

According to a recent article published by the Independent Lubricant Manufacturers Association, API Group III suppliers have begun placing customers on allocation, as well as shifting from contract to higher posted prices. ILMA anticipates that Group II refiners may be next as refinery economics incentivize a shift toward diesel production. (The ILMA article is provided at the end of this article.)

So what will a shortage mean for industrial equipment operators?

A Regional War, A Narrow Strait, and a Global Supply Chain

The news of 2026 has been dominated by a regional war in the Middle East, involving the US, Iran, Israel, and gradually drawing in other countries in the region. Along with the obvious difficulties associated with regional armed conflict, the war has had a focused and concentrated impact on the narrow opening between Iran and the Arabian peninsula known as the Straight of Hormuz.

A high-traffic and very narrow maritime passage, the straight provides the only route from the Persian Gulf to the open ocean, and with it, much of the world’s petroleum shipments. Prior to the start of the war, about 20% of the world’s liquefied natural gas (LNG) and 25% of seaborne oil trade was passing through the strait every year. It is also a major route of petroleum products for Europe and Asia, and the only maritime route for several Gulf countries including the UAE, Qatar, Bahrain, Kuwait, and Iraq.

As Iran came under attack, the response included missile strikes on neighboring countries, including UAE, Kuwait, and Bahrain. More recently, escalation of hostilities has resulted in both a threatened “closure” of the straight by Iran, and countered shortly thereafter by an embargo of the region by the US Navy. Eventually, it became clear that the earlier missile strikes had disabled several key lubricant production facilities, including the ADNOC base oil facility in Abu Dhabi. Together, these impacts show the potential to specifically disrupt key formulated lubricant products to a degree never seen before.

The Industry Conversation Has Already Started

These developing factors became the topic of a late-scheduled, but well-attended special panel discussion at the recent STLE meeting in New Orleans. Moderated by Doug Sackett of Dilmar Oil Company. Panel members included Dennis Bachelder of API, Neil Canter of Chemical Solutions, James Carroll of Schaeffler, and Gary Dudley of GKD Consulting. Among the important points discussed during the panel was a warning from Neil Canter that the shortfall may be hitting crisis levels in the June-July timeframe, which is not a distant future concern, but NOW. The projections shared by the panel included rationing of the lubricant supply to dealers, noticeable shortages of automobile lubricants, and the potential for manufacturer’s and production facilities to be unable to procure the lubricants necessary for outages and turnarounds.

So the question becomes: what should the operators of lubricated assets be doing to mitigate their risk? While not a realistic strategy, it may be inevitable that some may try to hoard or stockpile lubricants in anticipation of these shortages. Those who study best lubrication practices realize that this is short-sighted, and may instead produce the opposite of the intended effect: mainly that the stored lubricants may suffer degradation and additive loss while stored and waiting for use.

A better strategy is for asset owners to review existing strategies and programs regarding lubricant use, consumption, and disposal. It is quite common that traditional time-based or machine usage-based lubricant replenishment programs consistently change out lubricants before they actually reach their end-of-life condition.

In the absence of data that can be used to drive the actions of lubricant reclamation or replenishment, calculations used to determine end of oil or grease life are filled with assumptions and guesses that rarely generate a replacement frequency that is anywhere near the optimal condition.

It is not to say that seminal research on calculating lubricant life is flawed or has been poorly developed. However, a close study of the inputs show that huge variations in projected lubricant life are imparted by user estimates of conditions of operation, including temperatures, vibrations, levels and damage potential of contaminants, and sealing effectiveness based on installed machine orientations. In other cases, broad generalizations about the machine conditions of operation are made by Original Equipment Manufacturers (OEMs), that result in conservative recommendations meant to be adequate for the worst possible conditions under which their equipment might be operated. The result is that lubricants are generally disposed of early in the potential lifecycle, artificially inflating the demand for lubricants and waste of a now even more precious asset.

Evidence That OEM Recommendations Often Underestimate Lubricant Life

Is there a basis for this assertion that remaining lubricant life is often diminished by the instructions provided by the OEMs? A case in point for greases was published in the Vertical Flight Society (VTOL) conference held in October 2020. Among the presentations was a summary of the findings of a Lubrication Optimization Study conducted by members of the Chinook Worldwide Owners Workshop (CWOW) to evaluate history and existing Boeing recommendations for grease replenishment across the airframe of this tandem rotor heavy-lift helicopter.

Case Study — Chinook Worldwide Owners Workshop (CWOW)

Lubrication Optimization Study, Vertical Flight Society (VTOL) Conference, October 2020

At the start of the study, the existing maintenance manual guidance ranged from 400 flight-hours for some components to as little as 50 flight-hours for the largest grease reservoirs protecting the swashplate bearings. After a grease sampling kit was developed and fielded to the participating military operators, over 1100 samples were submitted for analysis to determine the typical grease life intervals under real field and operating conditions. With 7 key parameters linked to end of grease life or requirements for purging of contaminants, the intervals across most of the greased components were expanded significantly, with only a few remaining at the historical intervals, and only 1 location requiring a decrease of the interval. (Go to GreaseThief.com for more insight).

The net impact of the study was a reduction of more than 50% of the historically used grease, while reducing labor required and more than doubling the time that the asset was available for use. These new recommendations were captured in the revised maintenance manual for the aircraft, and adopted by the participating militaries for their maintenance programs.

What can be done to protect yourself and your operations from the pending disruption?

When it comes to lubricating oils, extending drain intervals based on oil analysis results is just the beginning. Asset operators need to begin thinking about strategies to deal with the threat of shortages and significant price increases. Consumers may need to find ways to work around traditional sources of supply. Which raises the question: are you drilling for oil (and grease) in your own plant? We propose six ways to “drill for oil”, by reducing demand through extending the usage of our existing supply.

Filtration instead of oil changes

Oil changes have been the catch-all method to address any degradation for most users. It seems simple, get rid of the bad oil, and put in good oil. But often the situation is not that simple. Oil changes rarely remove all of a system’s oil, and some is left behind in piping, component housings, and reservoir low-points. The result is an ineffective addressing of the problems present in the oil.

If the primary driver for a change is a contaminant, then often a more effective way to address this is by using removal systems that address the contaminant(s) in question. Filtration, vacuum dehydration and even advanced systems that remove varnish and their pre-cursors can be ways to put off a scheduled oil change, and extend the life of the oil that has already been purchased and installed.

Sample every reservoir

When the interval-based PM says you need to order new oil and do a replacement, first check the oil analysis results to see if it is really needed. Often, oil “scheduled” for replacement indeed has remaining life. Condition-based oil changes can have a significant impact on the demand for new lubricant. Doubling the life of the oil (or even longer) is not unheard of. If you don’t have the data to confirm that its time to change, you are relying on estimates and guesses.

Sample grease-lubricated machinery

So if Condition-based strategy is effective for oils, why not greases? For years, this didn’t seem like a valid strategy due to challenges in sampling and limited options for analysis. But with the American Society for Testing and Materials (ASTM) having introduced standards for Inservice Sampling (D7718) and Integrated Tester method for Analysis (D7918), these limitations are gone.

The result is numerous industries and applications demonstrating the value of optimized grease replenishment. Multiple examples exist of historical interval-based grease replenishments being reduced by half when grease analysis is used to direct optimal replenishments instead. The savings are in reduced grease purchases, but also in reduced labor and disposal costs.

Re-additization for large volume reservoirs

While there has been more focus recently in developing solutions to extend lubricant life, large reservoirs and oil quantities have been considered and occasionally acted on by attempting to re-introduce depleted additives. The most logical example could be the replenishment of anti-oxidant additives, when oil analysis identifies a decreasing trend. Never as simple as just pouring some concentrated liquid additives into the reservoir, a careful plan of mixing and re-introduction, in partnership with the lubricant formulator, has proven successful in many cases. Other additives, like depleted anti-foam or demulsibility additives can sometimes be restored in this way, with the result being an extension of oil life and reduction of demand. At the very minimum, bleeding off a quarter of a sump’s volume, and adding that quantity of new oil back to the reservoir provides the means to extend the useful lifetime of the oil/lubricant.

Extending varnish-threatened oil life with solubility enhancers

Turbine oils are usually found in large-volume reservoirs, and the implication of imminent oil changes can cause concern and pushback on the substantial hit that brings to the budget. One of the more recent developments in oil life-extension strategies is the introduction of solubility enhancers. The appearance of Group II base oils in the primary turbine oil formulations has had the effect of increasing the occurrence of deposited varnish, and in a manner much more sudden and unexpected than the historical experience with Group I oils.

Fluitec, has been at the front lines of varnish monitoring, starting with the Linear Sweep Voltammetry of the RULER device, and continuing with the introduction and standardization of the Membrane Patch Colorimetry test. With eyes on the oil oxidation process, a natural extension is the search for solutions, and the introduction of solubility enhancers tuned to the chemistry of the degraded lubricant and its additives. Now partnered with ExxonMobil, a new strategy exists to extend the life of turbine oils, and reduce demand for the replacement and refilling of some very large reservoirs.

Invest a few thousand $ in an ultrasound unit and training to reduce greasing demand

Finally, and back to the focus on reducing grease demand, is the complementary technology of ultrasound monitoring. Greasing is often overlooked as a precision process, with many practitioners treating grease as a necessary evil, a low-cost product that can prevent high-dollar damage and repairs. But sometimes, greasing itself is the problem, and over-greasing is generally recognized as a bigger contributor to bearing failure than under-greasing.

Regardless of impact, the goal should always be (especially with scarce and expensive resources) to optimize use, so that only as much as is necessary for reliable operation is used.

Treating greasing as an imprecise method and merely a way to flush out the bearings results in wasted grease, labor and costs of handling and disposal. In the same way that grease analysis can help to pinpoint the degradation rates of grease in a particular application, ultrasound can be applied at the user interface, and provide real-time feedback to the greasing process to avoid over-lubrication, while ensuring that a reliable, consistent protective film is maintained. And even this technology continues to advance, as major ultrasound device developers have introduced solutions for automatic lubrication. In the same way that grease intervals are calculated for manual grease routes, autolubers rely on calculations derived from speed factors, and multiple conditional factors, including contaminant levels and severities, orientation of the shaft, vibration and other issues, that can only be estimated or guessed at. Because these condition factors are imprecise, greasing without condition data generally results in non-optimized delivery, and because under-lubrication has the immediate effect of bearing damage, the overwhelming tendency is to over-lubricate greased bearings.

The post Give it to me Straight: Are we headed to a Lube Supply Crisis? appeared first on Precision Lubrication.

Data Centers Are Redefining What a Lubricant Is

Greg Livingstone — Tue, 14 Apr 2026 20:20:08 +0000

The Lubricant That Doesn’t Lubricate

The fastest-growing fluid market for companies like ExxonMobil, Shell, FUCHS, Castrol, and Lubrizol has nothing to do with turbines, hydraulic presses, or gearboxes. It’s a stainless steel tank full of servers submerged in dielectric fluid.

The data center immersion cooling fluids market is projected to grow from roughly $190 million in 2025 to over $840 million by 2032, expanding at nearly 24% annually. By the broader measure of the total immersion cooling market, including hardware and integration, some analysts put the 2025 figure above $4 billion.

These fluids never form a hydrodynamic film. They never protect metal-to-metal contact. They carry no EP or AW additive packages. And yet the companies formulating and selling them are the same organizations that fill your lubricant reservoirs. The base stock chemistries, the supply chains, and increasingly the technical service models are converging.

Figure 1: Server boards submerged in dielectric cooling fluid inside a single-phase immersion tank. The fluid, a synthetic hydrocarbon, absorbs heat directly from processors, memory, and power delivery components without the need for fans or airflow management.

Why “Lubrication” Is Moving into Thermal Management

Up to 40% of the energy consumed by a typical data center goes toward preventing it from overheating. That was manageable when servers ran at moderate power densities and air cooling could handle the load. It is no longer manageable. AI training clusters routinely push rack power densities above 50 kW, and next-generation GPU (Graphics Processing Unit) configurations are targeting 100 kW per rack and beyond. Air resists heat transfer, which is the reason that double-pane windows insulate a room so well. Water conducts heat roughly 25 times better than air at rest. In motion, the gap widens further.

A May 2025 lifecycle assessment published in Nature by researchers at Microsoft and WSP Global quantified the efficiency gains across three liquid cooling technologies compared to traditional air cooling. Cold plate systems delivered a 15% reduction in energy consumption and a 31% decrease in water use. Single-phase immersion improved those numbers to 15% and 45%, respectively. Two-phase immersion outperformed both, yielding a 20% energy reduction and 48% less water consumption.

Goldman Sachs estimates that data centers already consume 1–2% of global electricity, a figure that could nearly double by the end of the decade. In Ireland, data centers account for roughly 17% of national electricity consumption and could reach a third by 2026. The U.S. Department of Energy estimates domestic data centers used more than 4.5% of total U.S. electricity in 2025, with cooling systems responsible for 25–40% of that draw.

For the lubrication community, the conceptual shift is this: in rotating machinery, the fluid manages friction and wear, with heat removal as a secondary function. In data center immersion, heat removal is the entire job. The fluid’s role flips from tribological to thermal. But the underlying science of fluid chemistry, oxidation stability, contamination control, and condition monitoring is remarkably similar.

Up to 40% of the energy consumed by a typical data center goes toward preventing it from overheating. Water conducts heat roughly 25 times better than air at rest. In motion, the gap widens further.

Immersion Fluids vs. Traditional Lubricants: What’s the Same, What’s Not

Immersion cooling comes in two fundamental variants:

Single-phase immersion uses synthetic hydrocarbons (polyalphaolefins, gas-to-liquid bases), synthetic esters, or bio-based oils that remain in liquid state throughout the cooling cycle. The fluid circulates through a tank containing fully submerged servers, absorbs heat by convection, and transfers it to a heat exchanger. Synthetic hydrocarbons held roughly 41% of the 2024 market revenue, favored for their low viscosity and strong material compatibility. These are chemically familiar to anyone who has worked with Group IV or Group V base stocks.

Two-phase immersion uses fluorinated chemistries, including hydrofluoroethers (HFEs), perfluorocarbons (PFCs), and hydrofluoroolefins (HFOs), that boil at low temperatures, typically 50–60°C. The phase change from liquid to vapor absorbs significantly more heat per unit volume than single-phase convection. It’s thermally superior, but as we’ll discuss, it carries serious regulatory and supply chain risk.

What should feel immediately familiar to lubrication professionals is the list of fluid performance parameters. The Open Compute Project (OCP), the industry’s primary standards body for data center hardware, has published a Base Specification for Immersion Fluids that reads like a lube oil spec sheet translated into a different application. Viscosity targets, thermal conductivity requirements, flash point minimums, pour point behavior, oxidative stability expectations. The OCP specification sets a single-phase viscosity target of 1.5 × 10⁻² N·s/m² at 40°C (approximately 17cSt at at 40°C), noting that lower viscosity fluids allow higher fin density in heatsink design and better thermal performance overall.

What’s different is the failure mode. In rotating machinery, inadequate lubrication leads to metal-to-metal contact, adhesive wear, and ultimately seizure. In immersion cooling, the catastrophic failure is thermal runaway, where the fluid can no longer remove heat fast enough and server components exceed their thermal limits. Dielectric strength replaces film thickness as the critical performance metric. There are no wear particles to count, but there are degradation byproducts to monitor, contamination limits to enforce, and material compatibility issues that will sound very familiar.

Side-by-Side: Industrial Lubricant vs. Immersion Cooling Fluid

Parameter	Industrial Lubricant	Immersion Cooling Fluid
Primary function	Friction reduction, wear protection	Heat removal, dielectric insulation
Base chemistries	Group I–V mineral & synthetic oils	PAO, GTL, synthetic esters, bio-oils, fluorochemicals
Viscosity focus	Film thickness at operating temp	Flow through heatsink fin channels
Additive packages	EP, AW, antioxidants, demulsifiers, many others	Minimal; antioxidants, metal deactivators
Failure mode	Wear, seizure, varnish deposition	Thermal runaway, dielectric breakdown
Key monitoring metric	Wear metals, viscosity, acid number	Dielectric strength, viscosity, acid number
Contamination control	ISO cleanliness codes, moisture	Particulate (≤25 μm), moisture, ionic residues
Material compatibility	Seals, paints, coatings	Cables, adhesives, PCB substrates, plastics
Operating temp range	40–120°C typical	40–70°C, continuous 24/7
Regulatory exposure	REACH, GHS, waste oil disposal	PFAS restrictions (two-phase), REACH, GHS

The Risk Landscape: Material Compatibility, Oxidation, and Contamination

The risks that data center operators are discovering are risks that lubrication professionals have been managing for decades.

Material compatibility is the most immediate concern. OCP’s material compatibility guidelines, published as an open-source reference document, warn that dielectric fluids can stiffen cable sheathing, remove identification markings, soften or dissolve adhesives and plastics, and interact unpredictably with certain coatings. The guidelines explicitly state that mineral oils should be avoided for immersion use due to impurities including sulfur, nitrogen, and aromatic compounds that create compatibility problems. Synthetic hydrocarbons and esters are the preferred chemistries.

Anyone who has managed a hydraulic system conversion or dealt with seal compatibility issues will be familiar with compatibility concerns. In a data center however, this concern is on a bigger scale. A single immersion tank can contain hundreds of servers, each with dozens of distinct materials in contact with the fluid. Cables, connectors, thermal interface materials, PCB substrates, conformal coatings, and adhesives all sit in the same bath. A compatibility failure is also on a larger scale than lubricants. Incompatibility doesn’t ruin a pump seal but destroys millions of dollars of compute hardware. Incompatibility examples can be seen in Figures 2 and 3.

A single immersion tank can contain hundreds of servers, each with dozens of distinct materials in contact with the fluid. A compatibility failure here doesn’t ruin a pump seal. It destroys millions of dollars of compute hardware.

Figure 2: Incompatibility may show up in the swelling of EPDM sealing and bending of terminal leads

Figure 3: Plasticizers, chlorine, sulfur may dissolve into the dielectric fluid.

Oxidation and degradation follow familiar pathways but with a different stress profile. Even though immersion systems are often designed as closed-loop, oxygen ingress is never zero. At sustained operating temperatures (typically 40–60°C bulk, with localized hot spots near chips exceeding 80–100°C), the fluid undergoes the same radical chain oxidation you see in lubricating oils. The rate accelerates with copper exposure from bus bars, connectors, and heat sinks, which act as potent catalysts.

But the oxidative stress is relentless: 24 hours a day, 365 days a year, with no shutdown cycles, no seasonal variation, and no opportunity for the fluid to rest. Oxidative degradation proceeds, acid numbers escalate, and fluid properties deteriorate. Therefore, monitoring these parameters matter in a server tank just as much as it does in a critical compressor train.

Contamination sensitivity in data center cooling systems is similar to many industrial lubricant cleanliness requirements. OCP’s August 2025 Technology Cooling System (TCS) guidance specifies that microchannel heat exchangers require filtration to below 25 μm. The document emphasizes that fluid quality standards, detailed flushing procedures, and biofilm prevention protocols are essential for reliable operation.

Pipe materials prone to corrosion, particularly carbon steel, are prohibited. Pre-commissioning guidelines call for deionized water flushes meeting ASTM D1193 conductivity requirements, hydrostatic pressure testing, and documented cleanliness verification before the first drop of coolant enters the system. Anyone who has managed an EHC or hydraulic system to low NAS 1638 or ISO 4406 cleanliness codes will recognize the criticality of contamination control.

“Forever Chemicals” Split the Market in Two

No discussion of immersion cooling fluids is complete without addressing PFAS (per- and polyfluoroalkyl), also referred to as Forever Chemicals. This family of chemicals has incredibly strong carbon-fluorine bonds that do not break down in the human body or in the environment, leading to toxic bioaccumulation.

In December 2022, 3M announced it would stop manufacturing all PFAS chemicals by the end of 2025. That single decision effectively destroyed the supply chain for two-phase immersion cooling in data centers. The three fluids that made the technology possible, Novec 7100, Novec 649, Fluorinert FC-72, are gone. The last day to place a new Novec order was March 31, 2025. 3M was staring down over 4,000 lawsuits and a $12.5 billion settlement with more than 11,000 U.S. public water systems alleging PFAS contamination in drinking water.

The three fluids that made two-phase immersion cooling possible, Novec 7100, Novec 649, Fluorinert FC-72, are gone. One corporate decision wiped out the entire supply chain.

The regulatory pressure extends well beyond 3M’s exit. The European Chemicals Agency (ECHA) is evaluating a PFAS restriction proposal submitted by five EU member states under REACH that covers over 10,000 substances. Updated proposals published in August 2025 expanded exemptions from 26 to 74, including longer transition periods for certain heat transfer applications. ECHA’s final opinions are expected by end of 2026, with European Commission restriction legislation anticipated in early 2027. In the United States, the EPA has classified certain PFAS compounds as hazardous substances, imposing stringent waste management and reporting requirements. Several U.S. states are pursuing their own restrictions.

The practical result is a bifurcation in the immersion cooling market. Single-phase systems using hydrocarbon-based fluids (PAOs, synthetic esters, bio-based oils) are positioned as the safe, scalable path. They avoid PFAS entirely and use chemistries that lubricant companies already manufacture at industrial scale.

Two-phase systems are in limbo, waiting for Chemours and others to commercialize PFAS-free alternatives like HFO-based fluids with zero ozone depletion potential. Commercial production of Chemours’ Opteon 2P50 is targeted for 2026, and Samsung has already qualified the fluid. But as one industry analysis noted, any vendor building a two-phase product around a fluorinated fluid is building on ground that may shift under them within 18 months.

For the lubrication community, the PFAS collapse is more than a data center story. PFAS are used in specialty lubricants and greases due to their superior heat resistance, antiwear and anticorrosion properties. These regulatory changes require reformulation of hundreds of greases and lubricants. It’s a good reminder that supply chain resilience isn’t just about having a backup supplier. It’s about understanding the regulatory trajectory of your base chemistries.

Who Owns the Fluid Spec? OEM vs. Operator Dynamics

In industrial rotating machinery, the power dynamic around fluid specifications is well established. The OEM, whether it’s Volvo, Siemens Energy or Caterpillar, publishes an approved lubricant list. The end user follows it, often because the equipment warranty depends on compliance. Lubricant suppliers invest heavily in OEM approvals. The OEM holds the leverage.

Data centers have inverted this model.

OCP’s specifications are publicly available, their meetings are open and recorded, and their technical documents are published under Creative Commons licensing. The lubrication industry doesn’t have anything like it.

The Open Compute Project (OCP) sits at the center of the emerging standards landscape. OCP’s Immersion Sub-Project operates through dedicated technical committees for Fluids, Solutions, Reliability, and IT Equipment integration. These committees are developing open-source specifications, reference designs, and best practices through a volunteer-driven process that unites technology providers, end users, researchers, and fluid manufacturers. Their Immersion Requirements sub-project exists specifically to separate marketing claims from engineering reality, ensuring what OCP calls “accurate and factual technology positioning.”

This is an open-standards approach to fluid qualification that doesn’t have a clear parallel in traditional lubrication. ASTM and ISO develop test methods, but they don’t publish application-specific fluid requirements the way OCP does. OEM lubricant approvals are proprietary and often opaque. OCP’s specifications are publicly available, their meetings are open and recorded, and their technical documents are published under Creative Commons licensing.

Meanwhile, the hyperscalers are writing their own rules. Microsoft, Google, and Meta have internal testing programs and qualification protocols that effectively function as proprietary fluid specifications. When Microsoft validates a two-phase immersion tank at its Quincy, Washington campus, or when Google standardizes immersion-cooled TPU pods across its fleet, those decisions influence the market. The hyperscalers have more testing infrastructure, more purchasing leverage, and more operational data than any traditional OEM.

Chip manufacturers add another layer. In May 2025, Shell became the first immersion fluid provider to receive certification from Intel for its 4th and 5th generation Xeon processors, including a warranty rider for immersion-cooled chips. Intel estimated the electricity consumption reduction at up to 48%. This mirrors how turbine OEMs approve specific lubricant brands, but the twist is that Intel isn’t the system integrator; it’s the component manufacturer inside someone else’s machine.

Colocation providers and enterprise data center operators don’t have Google’s testing labs or Microsoft’s engineering teams. They need standardized, vendor-neutral fluid specifications they can trust. That is exactly the role OCP is filling, and it represents a model the lubrication industry could learn from. OCP’s transparent, committee-driven approach to fluid qualification stands in contrast to the often opaque process by which industrial OEMs approve or delist lubricants.

Why Lubricant Companies Are Repositioning Around Data Centers

The number of companies competing in the immersion cooling fluids market tells the story. Shell, ExxonMobil, Castrol, FUCHS, Lubrizol, Valvoline, TotalEnergies, PETRONAS, Cargill, and ENEOS are some of the major lubricant companies focused on data center immersion coolants.

Industrial lubricant volumes in traditional applications are mature in most developed markets. Electrification is shrinking some automotive and drivetrain lubricant categories. Data center fluids offer a new, high-growth volume play using chemistries these companies already manufacture. PAOs, synthetic esters, Group III+ bases, and bio-based oils are all viable single-phase immersion fluids.

Lubricant companies bring global supply chain scale, established quality management programs and technical service teams with decades of experience in condition monitoring and fluid analysis. In addition, they have deep institutional knowledge of oxidation chemistry, additive interactions, and degradation mechanisms. A lubricant company that already produces thousands of tons of PAO annually doesn’t face the same scale-up challenges as a venture-backed fluid startup trying to commercialize a novel chemistry.

Industrial lubricant volumes in traditional applications are mature. Electrification is shrinking some categories. Data center fluids offer a new, high-growth volume play using chemistries these companies already manufacture.

Oil manufacturers are also focused on the sustainability aspect. TotalEnergies’ BioLife product line demonstrates that plant-based fluid stocks can match petrochemical performance while biodegrading rapidly enough to satisfy EU waste directives. Cargill brings agricultural feedstock expertise. Bio-based lubricants have been a perennial topic at lubrication conferences for years. Data centers are giving the category a new, high-volume market to accelerate product development.

FUCHS has been particularly aggressive, signing a long-term partnership with Anhui Zhongding Intelligent Thermal Management Systems in China for data center immersion solutions in January 2024. Shell’s Intel certification positions it as the trusted fluid in one of the largest chip ecosystems on earth. Lubricant companies are quickly capitalizing on these emerging data center opportunities.

What This Means for Lubrication Professionals

The skills that define precision lubrication, fluid analysis, contamination control, material compatibility assessment, condition-based maintenance, and the ability to understand degradation mechanisms at a molecular level, are exactly what data center operators need as they transition from air to liquid cooling. The application is different. But the science is the same.

Consider what the OCP’s own documentation demands. Regular fluid testing with defined alarm limits. Material compatibility protocols. Cleanliness targets for particulate and ionic contamination. Flushing and commissioning procedures. Biofilm monitoring. Thermal performance trending over the fluid’s service life. These are the same program elements that world class lubrication programs require.

The data center immersion cooling market is growing at nearly 24% annually. The broader liquid cooling market nearly doubled in 2025, approaching $3 billion, and is forecast to reach $7 billion by 2029. Only 45% of data centers now run purely on air cooling, down from 48% just a year earlier, with 59% planning to implement liquid cooling within five years. This is a rapidly evolving market where fluids expertise will be demanded.

The definition of “lubricant” is expanding. It now includes fluids that never touch a bearing but carry the same chemical DNA, require the same analytical rigor, and depend on the same foundational science. The professionals who recognize this early won’t just watch the transition. They’ll lead it.

The Data Center Power Boom and What It Means for Traditional Lubrication Markets

The conversation about data centers and fluids tends to focus on what’s inside the server tank. Immersion cooling is new, it’s technically interesting, and it represents a genuine expansion of what the word “lubricant” means. But there is a second story running in parallel that may impact the lubrication industry’s bottom line. Power generation.

The scale of the power buildout is difficult to overstate. The International Energy Agency projects that global data center electricity consumption will roughly double to around 945 TWh by 2030, growing at about 15% per year. That growth rate is more than four times faster than electricity consumption growth from all other sectors combined. Gartner’s estimate is even higher, projecting worldwide data center electricity consumption will rise from 448 TWh in 2025 to 980 TWh by 2030. In the United States specifically, data centers consumed approximately 176 TWh in 2023, roughly 4.4% of total national electricity. The Department of Energy and Lawrence Berkeley National Laboratory project that figure could reach 6.7% to 12% of all U.S. electricity consumption by 2028.

Gas turbines are the biggest technology in this buildout. Natural gas supplied more than 40% of U.S. utility-scale electricity in 2023, and developers currently plan 18.7 GW of newly constructed combined-cycle gas turbine capacity through 2028. Globally, gas-fired power capacity in development rose 31% in 2025 alone, reaching a total of 1,047 GW across all stages of planning and construction. The Global Energy Monitor reports that 2026 could set a record for new gas power projects coming online, potentially exceeding the previous high of 100 GW added in 2002 during the wave of gas-fired construction that followed electricity market deregulation.

Data centers are a primary driver of this surge. Meta’s Hyperion project in Louisiana will use three H-class natural gas turbines as part of a facility that will eventually scale to 5 GW. Elon Musk’s xAI has ordered up to 60 gas turbines for its Memphis supercomputer facility. Boom Supersonic signed a $1.25 billion deal to supply Crusoe, an OpenAI data center developer, with 29 jet-engine-derived gas turbines. The Oracle/OpenAI Stargate project in Abilene, Texas is deploying GE Vernova and Solar Turbines units to deliver more than 1 GW of on-site power. Industrial Info Resources expects natural gas power plant investment to top $35 billion annually and sustain that level for several years, reaching a pace of construction not seen in two decades.

Gas turbine lead times have stretched to five to seven years in some cases, and turbine prices have risen 195% since 2019 according to Wood Mackenzie, reflecting the intensity of demand. OEMs like GE Vernova, Siemens, and Mitsubishi Heavy Industries report order backlogs at record highs.

Diesel generators represent a hidden fleet of enormous scale. Data centers require backup power systems capable of sustaining the full facility load during grid outages, and diesel generators remain the dominant technology. Just in the state of Virginia alone, over 10,500 diesel generator units had been permitted for data centers by the end of 2025, with a total capacity of 27 GW. That is equivalent to the power usage of roughly 20 million U.S. households, in a state with fewer than 4 million homes. Nationwide, the U.S. data center backup diesel fleet is expected to approach 67 GW of installed capacity by the end of the decade, roughly 35 nuclear power plants worth of generating capacity.

Virginia alone has permitted over 10,500 diesel generator units for data centers, with 27 GW of total capacity. That’s enough to power roughly 20 million U.S. households, in a state with fewer than 4 million homes.

A new class of power plant operator. More than 25% of new data center facilities above 500 MW will have behind-the-meter power generation by 2030, up from just 1% today. This means data center operators will be managing their own gas turbines, reciprocating engines, and combined-cycle plants, not the grid utility. Many of these data center operators have deep expertise in IT infrastructure and thermal management but no institutional experience managing rotating equipment maintenance programs. They will need lubrication engineers, fluid analysis programs, vibration monitoring, and contamination control technologies.

Renewables complete the picture. The data center buildout is simultaneously driving renewable energy procurement at unprecedented scale. Microsoft, Google, Amazon, and Meta are among the world’s largest corporate buyers of wind and solar capacity. In Europe, the major hyperscalers each account for roughly 4 to 9 GW of total corporate energy procurement.

The data center industry doesn’t just redefine what a lubricant is. It amplifies demand for every lubricant category that already exists: gas turbine oils, diesel engine oils, hydraulic fluids, wind turbine gear oils, and grease. Where turbines go, lubrication programs follow.

References

Open Compute Project, “Immersion Sub-Project Overview,” OCP Cooling Environments, 2025. Available: https://www.opencompute.org/projects/immersion
Open Compute Project, “Base Specification for Immersion Fluids,” Revision 1.0, Version 1.0, December 2022. Available: https://www.opencompute.org/documents/ocp-base-specification-for-immersion-fluids-20221201-pdf
Open Compute Project, “Material Compatibility in Immersion Cooling,” Version 1.0, November 2022. Available: https://www.opencompute.org/documents/material-compatibility-in-immersion-cooling-document-version-1-0-nov-28-2022-1-pdf
Open Compute Project, “OCP Immersion Requirements,” Revision 2.1, August 2023. Available: https://www.opencompute.org/documents/ocp-acs-immersion-requirements-rev-2-1-pdf
Open Compute Project, “Modular Technology Cooling System for Cloud Scale,” Revision 1, August 2025. Available: https://www.opencompute.org/documents/ocp-modular-tcs-rev-1-final-2025-pdf
Open Compute Project, “Guidelines for Pre-Commission Preparation of Technology Cooling System (TCS) Row Manifolds,” March 2025. Available: https://www.opencompute.org/wiki/Cooling_Environments/Immersion
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The post Data Centers Are Redefining What a Lubricant Is appeared first on Precision Lubrication.

Why Condition Monitoring Demands More Than Vibration Alone Today

Matt Spurlock — Tue, 14 Apr 2026 19:56:33 +0000

Condition monitoring is sometimes portrayed in industry messaging as being effectively limited to vibration analysis and ultrasound. Such claims, including those recently advanced by emerging vendors in the sensing technology space, reflect a broader pattern of marketing-driven simplification rather than technical accuracy. International standards define condition monitoring as a process that incorporates multiple diagnostic techniques, including lubricant analysis, vibration, thermography, and electrical methods ¹.

Reliability-centered maintenance theory further emphasizes that different technologies are required to detect distinct failure modes and stages of degradation ². Empirical research in predictive maintenance consistently demonstrates that no single method provides complete fault coverage across all mechanical systems ³. These foundational perspectives establish that condition monitoring must be understood as an integrated, multi-technology framework rather than a simplified binary construct.

Condition monitoring must be understood as an integrated, multi-technology framework rather than a simplified binary construct.

Oil analysis is a critical component of this framework because it can detect early-stage degradation and identify the root causes of failure. Oil analysis is formally recognized as a primary condition monitoring method capable of evaluating lubricant condition, contamination, and wear debris as indicators of machine health ¹. Standardized testing methods developed by ASTM provide consistent procedures for assessing these parameters across a wide range of equipment types ⁷.

In particular, tribological research demonstrates that wear particle generation occurs at the onset of failure mechanisms, often preceding measurable changes in vibration signatures ⁴. Furthermore, applied studies in machinery diagnostics show that oil analysis frequently identifies incipient faults earlier than vibration-based methods in rotating equipment systems ⁶. Accordingly, this article directly challenges reductionist claims by demonstrating that condition monitoring is inherently multi-modal and that oil analysis plays a critical, often leading role in fault detection and diagnosis.

Condition Monitoring as a Multi-Technology Framework

Standards and Established Practice

Condition monitoring is fundamentally structured as a multi-technology discipline designed to capture different dimensions of machine degradation. ISO 17359 explicitly identifies lubricant analysis as a primary condition-monitoring technique, alongside vibration and other diagnostic methods ¹. Furthermore, reliability-centered maintenance frameworks reinforce that the selection of monitoring technologies must align with specific failure mechanisms rather than convenience or convention ².

In addition, industry research demonstrates that combining multiple technologies significantly improves fault detection accuracy and reduces the risk of missed failures ³. Taken together, these perspectives confirm that any attempt to reduce condition monitoring to a limited subset of technologies is inconsistent with established practice.

Any attempt to reduce condition monitoring to a limited subset of technologies is inconsistent with established practice.

This broader context underscores the need to examine how different technologies contribute uniquely to fault detection.

Failure Mechanism Complexity

The necessity of multiple technologies becomes more evident when considering the complexity of failure mechanisms in rotating equipment. Mechanical systems experience degradation through processes such as wear, fatigue, corrosion, and contamination ⁸. Notably, each process produces distinct physical and chemical signatures that are not uniformly detectable by a single monitoring method ⁵.

Moreover, empirical studies have shown that certain faults remain undetected when relying exclusively on vibration or acoustic methods ⁹. Consequently, this complexity reinforces—not merely suggests—the need for oil analysis within a comprehensive monitoring strategy.

Oil Analysis as a Foundational Diagnostic Method

Lubricant Condition and Wear Assessment

Oil analysis serves as a foundational diagnostic method by providing direct insight into both lubricant condition and machine wear. Standard practices defined by ASTM establish oil analysis as a structured approach for monitoring viscosity, oxidation, contamination, and wear metals ⁷. In particular, tribological research confirms that lubricants act as carriers of wear debris and contaminants, effectively transporting evidence of internal machine conditions ⁴.

Additionally, engineering studies demonstrate that oil analysis enables simultaneous evaluation of mechanical and chemical degradation processes ⁵. As a result, this dual capability distinguishes oil analysis from external sensing methods that rely solely on energy measurement. This distinction becomes particularly important when precise diagnostic resolution is required for effective maintenance decisions.

Characterizing Wear Mechanisms

The diagnostic depth of oil analysis is further enhanced by its ability to characterize wear mechanisms. Analytical ferrography and particle analysis techniques allow for the identification of wear modes such as abrasion, adhesion, and fatigue ⁹. Likewise, elemental spectroscopy provides additional resolution by linking detected metals to specific machine components ⁶.

Together, these capabilities enable practitioners to move beyond fault detection and toward precise failure diagnosis. Consequently, this level of diagnostic resolution establishes oil analysis as a critical tool for understanding the underlying causes of machine degradation.

Early Fault Detection and the Failure Progression Curve

Detection at the Point of Origin

Oil analysis enables earlier fault detection by identifying degradation at the point of origin within the machine. Wear particles are generated during the initial stages of material interaction, often before significant energy is produced ⁴.

In fact, empirical studies have shown that wear debris analysis can detect bearing and gear faults months in advance of vibration-based detection thresholds ⁶. In applied industrial settings, advanced lubricant data analysis has demonstrated the potential to extend this detection window significantly, in some cases approaching multiple years of advanced indication.

Wear debris analysis can detect bearing and gear faults months in advance of vibration-based detection thresholds.

Furthermore, additional research indicates that early-stage contamination and lubricant degradation can be identified before they result in measurable mechanical symptoms ⁵. As a result, these findings demonstrate that oil analysis operates at the earliest portion of the failure progression curve. This early positioning is best understood within the context of reliability engineering models.

The P–F Interval Advantage

The temporal advantage of oil analysis is best understood within the context of the P–F interval. Reliability literature defines the P–F interval as the time between detectable potential failure and functional failure ². Importantly, technologies that detect faults earlier within this interval provide a greater opportunity for corrective action and risk mitigation ³.

In contrast, comparative studies have shown that vibration analysis often detects faults at later stages when damage has progressed sufficiently to affect machine dynamics ⁹. Therefore, this positioning highlights the strategic value of oil analysis in extending the predictive maintenance window.

Root Cause Identification and Diagnostic Resolution

Particle Morphology and Elemental Analysis

Oil analysis provides diagnostic resolution that enables the identification of root causes of failure. Wear particle morphology allows analysts to distinguish between different wear mechanisms based on particle size, shape, and texture ⁴. Elemental analysis further supports root cause identification by associating specific metals with machine components ⁶.

Contamination analysis reveals external influences such as dirt ingress or water contamination that contribute to accelerated wear ⁵. These capabilities allow oil analysis to move beyond symptom detection and toward causal diagnosis. This ability to identify underlying causes has direct implications for maintenance effectiveness.

From Symptoms to Causes

The ability to identify root causes has significant implications for maintenance strategy. Corrective actions based on root cause analysis are more effective than those based solely on symptom detection ³. Studies in reliability engineering have demonstrated that addressing underlying causes reduces recurrence rates and improves equipment lifespan ².

Corrective actions based on root cause analysis are more effective than those based solely on symptom detection.

In contrast, technologies that primarily detect symptoms may require additional analysis to determine the source of failure ⁹. This distinction reinforces the importance of oil analysis within a comprehensive diagnostic framework.

Internal Access Versus External Measurement

The Lubricant as a Diagnostic Medium

Oil analysis provides direct access to the internal operating environment of machinery. Lubricants circulate through critical components, collecting information about wear, contamination, and chemical changes ⁵. As such, tribological studies confirm that this internal perspective allows for the detection of conditions that are not immediately observable through external measurement ⁸.

Moreover, wear debris transported in the lubricant reflects real-time interactions occurring at the surface level of machine components ⁴. Consequently, this internal visibility provides a unique diagnostic advantage. This advantage becomes more apparent when contrasted with external sensing approaches.

Limitations of External Sensing

External sensing technologies, including vibration and ultrasound, rely on detecting energy transmitted through machine structures. By comparison, these methods require faults to reach a severity level that produces measurable signals ⁹. Additionally, signal interpretation can be influenced by factors such as machine geometry and operating conditions ³.

As a result, certain early-stage faults may remain undetected until they progress further. This contrast highlights the complementary nature of internal and external monitoring approaches, particularly when evaluating the limitations of any single diagnostic method.

Limitations of Vibration and Ultrasound as Exclusive Solutions

Detection Gaps in Single-Technology Approaches

Vibration and ultrasound are valuable diagnostic tools, but are limited when used as standalone solutions. Vibration analysis is highly effective for detecting imbalance, misalignment, and looseness, but is less sensitive to early-stage wear in low-energy conditions ³. Ultrasound can detect friction-related phenomena but provides limited information regarding wear mechanisms and contamination sources ⁹.

Research has shown that reliance on a single technology increases the likelihood of missed or delayed fault detection ². These limitations underscore the need for a multi-technology approach. This recognition leads directly to the importance of integrating complementary diagnostic methods.

Closing the Gap with Oil Analysis

The integration of oil analysis addresses many of these limitations by providing complementary data. Oil analysis captures early-stage degradation and identifies root causes, while vibration and ultrasound provide information about fault severity and dynamic behavior ⁵.

Studies in predictive maintenance demonstrate that combining these methods improves diagnostic accuracy and maintenance decision-making ³. This integrated approach aligns with best practices in reliability engineering and forms the basis for modern condition monitoring strategies.

Integration of Technologies in Modern Reliability Practice

Complementary Diagnostics as Core Principle

Modern reliability practice formalizes the integration of multiple condition monitoring technologies as a core operational principle. Reliability-centered maintenance frameworks advocate for the use of complementary diagnostic tools to address different failure modes ². Industry research demonstrates that integrated monitoring programs achieve higher reliability and lower maintenance costs than single-technology approaches ³.

Tribological and mechanical studies confirm that combining internal and external monitoring methods provides a more complete understanding of machine condition ⁸. These findings support a holistic approach to condition monitoring. This holistic approach is essential for maximizing diagnostic effectiveness.

Building a Comprehensive Diagnostic System

The integration of oil analysis with vibration and ultrasound creates a comprehensive diagnostic system. Oil analysis provides early detection and root cause identification, while vibration and ultrasound assess fault progression and severity ⁵. This combination enables more informed maintenance decisions and reduces the risk of unexpected failures ⁹.

Integrated monitoring programs achieve higher reliability and lower maintenance costs than single-technology approaches.

The resulting synergy enhances both detection capability and diagnostic accuracy. This integrated perspective provides the foundation for evaluating reductionist claims.

Conclusion

The assertion that condition monitoring has been reduced to vibration analysis and ultrasound is inconsistent with established standards, empirical research, and practical application. Oil analysis is recognized as a primary condition-monitoring technology in international standards and provides unique capabilities for early fault detection and root-cause identification ¹. Furthermore, tribological and engineering research demonstrates that oil analysis detects degradation at its origin and offers diagnostic insights not available through external sensing methods ^4,5.

In addition, reliability frameworks confirm that effective condition monitoring requires integrating multiple technologies rather than relying on a single approach ². Therefore, a more accurate and defensible position is that condition monitoring is a multi-technology discipline in which oil analysis plays a critical and often leading role in identifying and diagnosing machine failure.

To suggest otherwise is misleading and reflects a reductionist narrative that prioritizes market positioning over technical accuracy.

Growth strategies that narrow the scope of condition monitoring do not improve reliability; rather, they dilute it.

As industry leaders, we have a responsibility to represent these technologies accurately and with integrity, ensuring that end users are equipped with the full range of tools necessary to detect, diagnose, and prevent failure. Ultimately, anything less is a disservice to the profession and the organizations that depend on it.

References

ISO. (2018). ISO 17359: Condition monitoring and diagnostics of machines—General guidelines.
Moubray, J. (1997). Reliability-Centered Maintenance.
Bloch, H. P., & Geitner, F. K. (2014). Machinery Failure Analysis and Troubleshooting.
Stachowiak, G. W., & Batchelor, A. W. (2014). Engineering Tribology.
Totten, G. E. (2006). Handbook of Lubrication and Tribology.
Macian, V., et al. (2003). Wear, 255, 1297–1305.
ASTM International. (2020). Standards for used oil analysis and condition monitoring.
Hutchings, I. M., & Shipway, P. (2017). Tribology: Friction and Wear of Engineering Materials.
Anderson, D. (2012). Oil Analysis Solutions.

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Wrong Oil Top-Up? Here’s How to Spot the Warning Signs Early

Martin Williamson — Tue, 14 Apr 2026 19:55:57 +0000

Over the years, I have come across instances where issues have arisen, such as the filters blinding prematurely. With testing, this has ultimately been identified as leaving the tank open in a paper mill, and an investigation of the elements highlighted this, along with the high particle counts.

There have been other root causes, such as mineral oil being added to a phosphate ester oil on an electro-hydraulic control system, or, in another case, the oil supplier putting engine oil in drums intended for turbine oil. In the latter case, within less than an hour of topping up the turbine tank with just one of the mislabelled drums, the filters were showing as blocked, and the turbine was out of service for six months.

Within less than an hour of topping up the turbine tank with just one mislabelled drum, the filters were blocked, and the turbine was out of service for six months.

A more confusing scenario was a switch in supplier for a bearing oil at a paper mill. The end-user was assured of compatibility, but it transpired that a difference in the additive package, combined with water ingress (it was a paper mill after all), led to deposits on the filter. This could so easily have been checked by a filter-compatibility test from the new oil supplier. Filter companies often offer this service as well.

Consequently, I tend to use the following checklist when clients experience sudden, premature filter blockages in a previously stable system.

In the first instance, however, it is always useful to ask what the last maintenance action was, as this is often the cause or at least a clue to the possible cause.

While a number of these were major incidents involving high costs, I still frequently encounter the “oil is just oil” issue, and top-ups on smaller machines have been made with the wrong oil.

I still frequently encounter the “oil is just oil” issue, and top-ups on smaller machines have been made with the wrong oil.

Typically, I might get a phone call along the lines of “Is it possible to see if the wrong oil has been used for a top-up?” To which my answer is always, “Let me guess, you found the wrong container next to the asset?” Invariably, the answer is always yes.

Field Checks Before the Lab

So, when it comes to testing for the wrong oils used as top-ups, before even considering a laboratory test, there are a few basics to consider first.

Simple Checks	Comment
Color	Only if the wrong oil is significantly different and ideally requires a comparable background to determine the change in color.
Smell/Odor	Only if the wrong oil is significantly different such as with Sulphur base EP oils.
Condition	Possible formation of gels or other insoluble product in the oil which may cause premature filter failures owing to increased pressure drops from the reaction by-products.
Temperature	Possible temperature change owing to incorrect viscosity – be aware that the temperature could go up if a higher viscosity is used but will go much higher if a lower viscosity is used.
Inspection	Increased levels of wear debris as seen on the mag-plug or when draining the oil.
Other Pointers	Incorrect containers left near the machinery.

What the Lab Results Reveal

When it comes to laboratory testing, ideally, two samples need to be sent: a sample of the correct oil from a container in the store, along with the suspect sample from the asset. Using a sample of the correct oil, fresh from a container, a reasonable baseline for inorganic additive levels can be established and used for comparison with the suspect oil.

In terms of testing, however, apart from the obvious chemical and physical properties, measured wear rates may be affected by incorrect oil, which will elevate the measured wear metals.

Oil Analysis Test	Comment
Viscosity	Only if the top-up oil is significantly different although there may be possible changes in the VI even if the viscosity is the same.
Acid Number	Only if the top-up oil is significantly different.
Base Number	Usually increases if top-ups occur but not ideal at identifying wrong oil unless non-engine oils have been used.
Elemental Spectroscopy	Useful at identifying additive element inconsistencies.
Fourier Transform Infrared (FTIR)	Probably the most effective test when compared against a new oil. Changes in Oxidation, Nitration and Sulphation levels, as well as Anti-Wear/Antioxidant levels, with potential reactions also showing.
Other Indicators	Changes in appearance, wear rates and RULER etc.

Ultimately, though, several lessons spring to mind that we would do well to remember:

Training and raising awareness of the need to avoid cross-mixing oils
The use of a color code system for lubricants, with the color code visible on the new containers in stores, on handling equipment, and on assets.
Guarantees backed up by insurance coverage from the suppliers when switching lubricant brands, but ideally, with technical testing.
Certificates of conformity for all new batches of lubricants supplied.
Random sampling of new oils, particularly for the high-cost assets.

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