Oil and Gas Corrosion Testing That Finds the Failure
Before Your Flowline Does
SPL reproduces your field’s temperature, pressure, shear, water cut, and CO₂ conditions, so you can rank inhibitors, qualify materials, and set treatment targets on defensible data.
How SPL Approaches Oil and Gas Corrosion Testing
Corrosion in a production system rarely traces back to one variable. Fluid composition, flow regime, operating conditions, metallurgy, and chemical treatment all interact, and that combination decides whether a line sees manageable general corrosion or aggressive localized attack. SPL builds every oil and gas corrosion testing program around those interactions.
Our Flow Assurance Laboratory in Katy, Texas, tests your produced water, crude, condensate, or synthetic brine against the metallurgy you run or plan to run, with and without the inhibitor you’re evaluating. Rotating-cage autoclaves hold temperature, pressure, shear, water cut, and CO₂ partial pressure at the values your system actually sees, so results reflect field behavior instead of a generic screening test. Every test matrix accounts for three factors:
- Thermodynamics: temperature, pressure, gas composition, and aqueous chemistry
- Fluid chemistry and flow: water cut, brine composition, CO₂ loading, inhibitor partitioning, and wall shear stress
- Metallurgy: alloy, microstructure, surface condition, and weld regions
Our corrosion specialists pair measured results with working knowledge of production operations. You get an evidence-based read on corrosion risk, material suitability, and chemical-treatment performance across your operating envelope, plus the defensible data you need to set corrosion KPIs, justify a chemical program, or support a material upgrade.
Corrosion Testing Services
Rotating-cage autoclaves reproduce high-temperature, high-pressure, high-shear conditions to show whether inhibitor films and iron carbonate scale hold up.
Dynamic HPHT Corrosion Testing
Corrosion Inhibitor Testing
Screen and rank formulations, find the minimum effective concentration, and compare alternatives under identical conditions.
Oil/Brine Partitioning Studies
Measure how much inhibitor stays in the aqueous phase to protect water-wet steel.
CO₂ Corrosion Assessment
Evaluate sweet corrosion at the CO₂ partial pressure your system actually sees.
Mass loss, pit depth, pit density, and scale adherence, measured after controlled coupon cleaning.
Surface and Pitting Evaluation
Materials and Weld Evaluation
Carbon steels, low-alloy steels, selected corrosion-resistant alloys, weldments, and heat-affected zones.
Inhibitor Efficiency Testing
Screen scale inhibitors, corrosion inhibitors, and combined packages for performance and compatibility.
Field Corrosion Investigations
Trace unexpected corrosion, deposits, or inhibitor underperformance back to the conditions behind them.
Corrosion Testing Capabilities
SPL’s custom rotating-cage autoclaves use electrically isolated coupon fixtures and controlled rotation speeds to model turbulent flow. We tailor each run to your field operating envelope.
| Test Variable | Typical SPL Capability |
|---|---|
| Temperature | Ambient to 450°F / 232°C |
| Total pressure | Up to 2,000 psi / 138 bar |
| CO₂ partial pressure | Defined by the client test matrix |
| Balance gas | Nitrogen, to reach target total pressure |
| Wall shear stress | Above 200 Pa, depending on configuration |
| Water cut | Approximately 1% to 100% |
| Aqueous phase | Synthetic brine or client-supplied produced water |
| Hydrocarbon phase | Crude oil, condensate, or client-supplied hydrocarbon |
| Corrosion inhibitor | Client-selected formulation and dosage range |
| Materials | Carbon steels, low-alloy steels, and selected corrosion-resistant alloys |
Corrosion Inhibitor Performance Testing
Dosage alone doesn’t decide inhibitor performance. An effective formulation has to reach the metal, survive the local flow, and stay available in the water phase. SPL runs uninhibited and inhibited tests side by side to support inhibitor ranking, minimum effective concentration, dose-response curves, high-shear persistence, and water-wet versus oil-wet evaluation. When a program calls for it, we pre-partition the inhibitor between your oil and brine and test the aqueous phase alone, showing how much protection actually reaches water-wet steel.
Materials and Metallurgy
SPL benchmarks carbon and low-alloy line-pipe steels under uninhibited and inhibited conditions to establish baseline corrosion rates and show when chemical treatment or a material upgrade becomes necessary. We also assess corrosion-resistant alloys for localized attack, pitting, and crevice effects in chloride- and CO₂-containing environments, and compare weldments and heat-affected zones with parent metal to catch preferential attack across a joint.
Current Scope: CO₂ and Non-Sour Systems
SPL currently offers corrosion testing for CO₂-containing and non-sour systems. SPL does not currently offer sour-gas testing involving H₂S. If your system contains H₂S or requires sour-service qualification, talk with SPL before you submit samples so we can help you identify the right testing pathway.
Start With Your Operating Envelope
To scope a test, SPL needs your metallurgy, temperature, CO₂ partial pressure, total pressure, flow severity, and fluid chemistry. Our checklist covers the full list, including inhibitor dosage range and comparison conditions. Send what you have, and our team will fill the gaps with you during scoping.
Frequently Asked Questions About SPL Measurement Services
What does oil and gas corrosion testing measure?
Oil and gas corrosion testing measures how fast, and in what way, metal loses wall thickness under representative production conditions. SPL reports gravimetric mass loss and corrosion rate, pit depth and pit density, and the coverage of corrosion-product scale such as iron carbonate. Side-by-side uninhibited and inhibited tests show how much protection a corrosion inhibitor delivers in your conditions.
Can SPL test corrosion inhibitors at high shear and high temperature?
Yes. SPL’s rotating-cage autoclaves test corrosion inhibitors at up to 2,000 psi and 450°F (232°C), with wall shear above 200 Pa depending on configuration and water cuts from about 1% to 100%. These tests show whether an inhibitor film survives high-velocity zones, chokes, and bends, and how the minimum effective concentration shifts as shear rises.
Does SPL offer sour service or H₂S corrosion testing?
No. SPL currently performs corrosion testing on CO₂-containing and non-sour systems only, and does not offer sour-gas testing involving H₂S. If your system contains H₂S or requires sour-service qualification, contact SPL before you ship samples. Our flow assurance team will review your conditions and help you identify an appropriate testing pathway for the project.
What standards does SPL follow for corrosion coupon testing?
SPL aligns corrosion coupon testing with recognized ASTM practices. We prepare and clean specimens based on ASTM G1, evaluate pitting in line with ASTM G46, and, where electrochemical data apply, calculate corrosion rates using ASTM G102. Controlled chemical cleaning removes corrosion products and adherent iron carbonate without stripping uncorroded base metal. That step prevents artificially low or negative corrosion rates and gives you defensible data for inhibitor and material decisions.
How long does a corrosion test program take?
Timing depends on the program. Test duration, the number of conditions in the matrix, uninhibited baseline runs, and post-test surface analysis all set the schedule. A single-condition screening test finishes sooner than a multi-inhibitor, multi-temperature ranking study. SPL confirms the schedule and reporting date during project scoping, before samples arrive, so you can plan chemical trials or material decisions around a firm date.
What information does SPL need to scope a corrosion test?
SPL typically needs your target metallurgy, test temperature, CO₂ partial pressure, total pressure, and anticipated flow severity or wall shear stress. We also ask for brine chemistry or a produced-water sample, the hydrocarbon phase if applicable, water cut, the inhibitor formulation and dosage range, test duration, and comparison conditions such as an uninhibited baseline. Field observations help too, including measured corrosion rates, deposits, solids, and operating constraints.
Where is SPL's corrosion testing lab, and can you test samples from other regions?
Yes. SPL performs corrosion testing at its Flow Assurance Laboratory in Katy, Texas, and accepts samples from operations across the United States. Operators ship produced water, crude oil, condensate, and production chemical samples to the Katy lab, and our team coordinates shipping requirements during scoping. Founded in 1944 and headquartered in Houston, SPL operates 30+ locations and supports upstream, midstream, and offshore clients nationwide.
Why should scale and corrosion inhibitors be tested together?
Mineral scale creates stagnant, chemically distinct zones at the metal surface. Those zones concentrate aggressive species, block corrosion inhibitor access, and drive under-deposit corrosion and pitting, even when bulk corrosion rates look manageable. A scale inhibitor that performs well on its own can also weaken corrosion inhibitor film persistence or precipitate with divalent ions. SPL screens scale inhibitors, corrosion inhibitors, and combined packages for compatibility, then confirms performance under flowing conditions.
Put Your Corrosion Control Program to the Test
Send us your operating envelope, your fluids, and the inhibitors on your shortlist. SPL will build a test matrix that reflects your field and deliver the defensible data you need to choose with confidence.