Geomembrane Resistance to Hydrocarbon Contamination | Guide
What is Geomembrane Resistance to Hydrocarbon Contamination
Geomembrane resistance to hydrocarbon contamination refers to the ability of polymeric liners to maintain their physical, chemical, and mechanical integrity when exposed to petroleum-based substances—including crude oil, refined fuels (gasoline, diesel, jet fuel), lubricating oils, hydraulic fluids, and petrochemical intermediates. For engineers and EPC contractors designing containment systems for tank farms, refineries, pipelines, and fuel storage facilities, understanding geomembrane resistance to hydrocarbon contamination is critical because hydrocarbon exposure can cause polymer swelling, plasticizer extraction, embrittlement, and stress cracking.
Industry data from 165 hydrocarbon containment projects shows that the single most common failure mechanism is not chemical attack of the polymer backbone, but rather swelling-induced stress cracking. Hydrocarbons diffuse into the amorphous regions of HDPE, causing volumetric swelling of 2-15% depending on the specific hydrocarbon and exposure conditions. This swelling creates internal stress, which—combined with external tensile stress from the installation—can initiate environmental stress cracking (ESC). This guide provides engineers and procurement managers with the technical framework for selecting geomembranes that resist hydrocarbon contamination over 20-50 year service lives.
Technical Specifications for Hydrocarbon Resistance
The following table defines key parameters that govern geomembrane resistance to hydrocarbon contamination.
| Parameter | Typical Value | Engineering Importance | Test Method |
|---|---|---|---|
| Swelling Ratio (HDPE in Hydrocarbon) | 2-15% (depends on hydrocarbon type) | Swelling indicates hydrocarbon absorption. Higher swelling = higher permeation and stress cracking risk. | ASTM D471 (immersion) |
| Permeation Rate (Hydrocarbons through HDPE) | 10⁻⁹ to 10⁻⁶ g·mm/(m²·day) | Permeation through the liner—even without visible failure—can contaminate groundwater. | ASTM F739 (permeation cell) |
| Tensile Retention After Exposure | ≥90% (after 90 days in fuel at 50°C) | Mechanical property retention after hydrocarbon exposure. | ASTM D638 (after immersion) |
| Elongation Retention After Exposure | ≥85% (after 90 days in fuel at 50°C) | Loss of elongation indicates embrittlement. | ASTM D638 (after immersion) |
| Stress Crack Resistance (NCTL) Retention | ≥75% of baseline (after hydrocarbon exposure) | Hydrocarbons can reduce stress crack resistance. PE100 with >500 hours baseline recommended. | ASTM D5397 (after immersion) |
| OIT Retention After Exposure | ≥80% (after 90 days in fuel at 50°C) | Hydrocarbons can extract antioxidants. CIP-grade recommended. | ASTM D3895 (after immersion) |
| Hardness Change (Shore D) | <5 point change | Significant hardness change indicates plasticization or degradation. | ASTM D2240 |
| Weight Change After Immersion | <5% (HDPE in most hydrocarbons) | Weight gain = hydrocarbon absorption. >5% indicates significant interaction. | ASTM D471 |
| Glass Transition Temperature (Tg) Shift | HDPE: Tg remains <-100°C | Tg shift indicates plasticization. HDPE maintains low Tg even after absorption. | DSC (Differential Scanning Calorimetry) |
| Recommended Resin Grade | PE100 (bimodal, high molecular weight) | Higher molecular weight provides better resistance to swelling-induced stress cracking. | MFI ≤0.25 |
| Recommended Additives | CIP-grade OIT >300 min; metal deactivator (if trace metals in hydrocarbon) | Antioxidants protect against oxidative degradation from hydrocarbon exposure. | ASTM D3895 |
| Expected Service Life (Hydrocarbon Exposure) | HDPE PE100: 30-50+ years; PVC: 5-15 years | HDPE is the preferred material for long-term hydrocarbon containment. | Field data + accelerated testing |
For procurement: When specifying geomembranes for hydrocarbon containment, require chemical immersion testing (ASTM D471 or D5747) in the specific hydrocarbon(s) expected at the site. Do not rely on generic "fuel-resistant" claims without test data.
Material Structure and Hydrocarbon Interaction
Understanding polymer structure explains why geomembrane resistance to hydrocarbon contamination varies by material.
| Component | Material | Function | Hydrocarbon Interaction |
|---|---|---|---|
| Polymer Matrix | HDPE (semi-crystalline) | Primary containment, strength | Hydrocarbons primarily affect amorphous regions. Crystalline regions are impermeable. PE100 has higher crystallinity (65-72%) than PE80 (60-65%)—better hydrocarbon resistance. |
| Amorphous Phase | Disordered HDPE chains | Energy dissipation, flexibility | Hydrocarbons diffuse into amorphous regions, causing swelling and chain mobility increase (plasticization). This reduces mechanical properties temporarily. Upon drying, some swelling is reversible. |
| Crystalline Phase | Ordered HDPE lamellae | Load-bearing, strength | Unaffected by hydrocarbon diffusion—non-permeable. Higher crystallinity = lower permeation and swelling. |
| Tie Molecules | Polymer chains bridging crystallites | Stress transfer, crack bridging | Hydrocarbon swelling strains tie molecules. PE100 (bimodal) has more tie molecules—better resistance to swelling-induced stress cracking. |
| Antioxidant Package | Hindered phenols + phosphites | Prevents oxidation | Hydrocarbons can extract some antioxidants. CIP-grade (higher loading) provides longer protection. |
| Carbon Black | 2-3% carbon black | UV stabilization | Unaffected by hydrocarbons. However, hydrocarbons can mobilize carbon black if the carrier resin is swollen. |
| Plasticizers (PVC) | Phthalates, adipates | Flexibility | Hydrocarbons extract plasticizers from PVC—PVC embrittles rapidly in fuel/oil contact. This is the primary reason PVC is not used for long-term hydrocarbon containment. |
| Stabilizers (PVC) | Metal soaps, organotins | Heat/UV stabilization | Can be extracted by hydrocarbons, accelerating degradation. |
Engineering reasoning: The geomembrane resistance to hydrocarbon contamination is governed by two primary mechanisms. First, permeation—hydrocarbons diffuse through the amorphous polymer matrix. This is a physical process driven by concentration gradient. Second, swelling—absorbed hydrocarbons occupy free volume in the amorphous regions, causing volumetric expansion. Swelling creates internal stress, particularly when the liner is constrained (e.g., at anchor trenches or welded seams). When combined with external tensile stress, swelling stress can exceed the stress crack resistance threshold, initiating ESC. For HDPE, swelling is generally reversible (upon drying, the hydrocarbon evaporates and the liner returns to original dimensions). However, repeated wet-dry cycles can cause cumulative damage.
For PVC, the mechanism is different—hydrocarbons extract plasticizers, permanently embrittling the material. PVC is not recommended for long-term hydrocarbon containment.
Manufacturing Process and Hydrocarbon Resistance
Production choices that improve geomembrane resistance to hydrocarbon contamination.
1. Raw Material Selection
Resin grade significantly affects hydrocarbon resistance. PE100 (bimodal, high molecular weight) has higher crystallinity and more tie molecules—better resistance to swelling and stress cracking. Hydrocarbon importance: Specify PE100 with MFI ≤0.25. Higher molecular weight chains are more resistant to disentanglement during swelling.
2. Compounding
CIP-grade antioxidants with metal deactivators are recommended for hydrocarbon applications—hydrocarbons can contain trace metals that catalyze oxidation. Hydrocarbon importance: Request OIT >300 min. For hydrocarbons with known trace metals (e.g., crude oil), specify metal deactivator additive.
3. Extrusion
Extrusion quality affects surface smoothness and thickness uniformity. Smooth surfaces have fewer stress risers. Hydrocarbon importance: Smooth liners (not textured) perform better in hydrocarbon environments because they have fewer surface irregularities for stress concentration.
4. Annealing
Annealing reduces residual stress, which reduces the driving force for swelling-induced stress cracking. Hydrocarbon importance: In hydrocarbon environments where swelling stress is a concern, specify annealed geomembrane.
5. Quality Inspection
Standard GRI GM13 testing is required. Additional testing for hydrocarbon applications: chemical immersion testing (ASTM D471 or D5747) in the specific hydrocarbon(s). Hydrocarbon verification: Request swelling ratio, tensile retention, and OIT retention after 90 days in hydrocarbon at 50°C.
6. Packaging and Storage
Standard UV protection. Store rolls in clean, dry areas—avoid hydrocarbon contamination during storage.
Performance Comparison: Hydrocarbon Resistance of Liner Materials
| Material | Hydrocarbon Swelling | Permeation Rate | Stress Crack Resistance in Hydrocarbon | Chemical Compatibility | Cost Level | Suitability for Hydrocarbon Containment |
|---|---|---|---|---|---|---|
| HDPE PE100 Smooth (CIP, Annealed) | 2-5% (fuel); 5-10% (crude) | Very low (10⁻⁸ to 10⁻⁷) | Excellent (retains >80% NCTL) | Excellent | $$$$ | Highly recommended—premium specification |
| HDPE PE100 Smooth (Standard OIT) | 2-5% (fuel); 5-10% (crude) | Very low | Excellent (retains >80% NCTL) | Excellent | $$$ | Recommended—but CIP preferred for long life |
| HDPE PE80 Smooth (CIP) | 3-6% (fuel); 8-15% (crude) | Low | Good (retains >70% NCTL) | Good | $$$ | Acceptable for moderate hydrocarbon exposure |
| HDPE Textured (Any Grade) | Same as smooth (but stress risers from texture) | Same as smooth | Reduced 30-50% (texture stress risers) | Good | $$$$ | Not recommended (texture creates crack initiation sites) |
| LLDPE Smooth | 4-8% (fuel); 10-18% (crude) | Moderate (higher than HDPE) | Good (lower crystallinity, higher swelling) | Good | $$ | Not recommended for long-term hydrocarbon |
| PVC (with plasticizers) | Low (swelling) but plasticizer extraction | Low (but material embrittles) | Poor (plasticizer loss → brittle) | Poor (plasticizer extraction) | $ | Not recommended for hydrocarbon containment |
| Polypropylene (PP) | 1-3% (fuel); 3-5% (crude) | Very low | Good | Good (but lower chemical resistance than HDPE to some solvents) | $$$$ | Suitable for high-temperature hydrocarbon (>50°C) |
| Reinforced HDPE (with scrim) | Similar to HDPE | Very low | Good (scrim restrains swelling) | Excellent | $$$$ | Floating covers, large reservoirs |
Procurement rule: For any hydrocarbon containment with design life >15 years, specify HDPE PE100 smooth, CIP-grade (OIT >300 min), annealed, with NCTL >500 hours. Avoid textured liners. For crude oil or heavy hydrocarbons, specify metal deactivator additive. For high-temperature hydrocarbon (>50°C), consider PP or reinforced HDPE.
Industrial Applications with Hydrocarbon Exposure
Tank Farms and Fuel Storage Facilities
Secondary containment for above-ground and underground storage tanks. Hydrocarbons: gasoline, diesel, jet fuel, crude oil. Design life: 20-30 years. Specification: 1.5-2.0mm HDPE PE100 smooth, CIP-grade, annealed, GRI GM13. Liner must resist fuel permeation and swelling.
Refinery Containment
Process areas with hydrocarbon spills and leaks. Hydrocarbons: crude oil, refined products, petrochemical intermediates (BTEX, naphtha). Design life: 25-35 years. Specification: 2.0-2.5mm HDPE PE100 smooth, CIP-grade (OIT >400 min), annealed, with metal deactivator. Double liner system often required.
Pipeline Containment (SPCC)
Secondary containment for oil and product pipelines. Hydrocarbons: crude oil, refined products. Design life: 20-30 years. Specification: 1.5-2.0mm HDPE PE100 smooth, CIP-grade, annealed. SPCC compliance requires liner compatibility with potential spills.
Oilfield Produced Water Ponds
Brine from oil and gas production—contains hydrocarbons (oil, grease), salts, trace metals, high temperature (40-80°C). Design life: 20-30 years. Specification: 2.0-2.5mm HDPE PE100 smooth, CIP-grade (OIT >400 min for high temperature), annealed, with metal deactivator. Additional: check for solvent compatibility (some produced water contains aromatic hydrocarbons).
Bulk Fuel Storage (Aviation, Marine)
Jet fuel, marine diesel, bunker fuel containment. Design life: 25-35 years. Specification: 2.0mm HDPE PE100 smooth, CIP-grade, annealed. ASTM F739 permeation testing required for fuel containment.
Landfills (Hydrocarbon Waste)
Landfills accepting petroleum-contaminated soil or oily waste. Leachate contains hydrocarbons. Design life: 20-30 years. Specification: 2.0mm HDPE PE100 smooth, CIP-grade, annealed. GRI GM13 certified.
Common Industry Problems and Engineering Solutions
Problem 1: Swelling-Induced Stress Cracking at Seam Toes
Root cause: Hydrocarbon absorption causes volumetric swelling (2-15%). The liner is constrained at welded seams (seam area has higher restraint). Swelling creates internal tensile stress at the seam toe. Combined with residual stress from welding, this exceeds the stress crack resistance threshold—cracks initiate and propagate. Solution: Specify PE100 with NCTL >500 hours (provides margin against swelling stress). Annealed liner reduces residual stress. Smooth (not textured) reduces stress risers. For critical hydrocarbon applications, consider stress-relief seams (welding with lower tension).
Problem 2: OIT Depletion and Oxidation from Hydrocarbon Exposure
Root cause: Hydrocarbons can extract antioxidants from the polymer. Trace metals in crude oil (Cu, Fe, Mn) catalyze oxidation. High temperature accelerates both effects. Solution: Specify CIP-grade OIT >300 min (or >400 min for >40°C). Specify metal deactivator additive for crude oil or produced water. Test OIT retention after 90 days in hydrocarbon at 50°C—accept >80% retention.
Problem 3: Permeation Through Liner (Contaminant Migration)
Root cause: Hydrocarbons diffuse through the amorphous regions of the polymer. Permeation occurs even without visible liner failure—contaminants can reach groundwater through the liner. Solution: Use thicker liner (2.0mm minimum, 2.5mm for critical) to increase diffusion path length. Specify PE100 (higher crystallinity = lower permeation). For critical applications, use double liner system with leak detection layer.
Problem 4: PVC Embrittlement from Plasticizer Extraction
Root cause: Hydrocarbons extract plasticizers from PVC, causing the material to become brittle and shrink. This is not reversible. Solution: Do not use PVC for hydrocarbon containment with design life >5 years. Use HDPE instead.
Risk Factors and Prevention Strategies
Hydrocarbon Type and Aromatic Content
Risk: Aromatic hydrocarbons (benzene, toluene, xylenes) have higher swelling potential than aliphatic hydrocarbons (diesel, mineral oil). BTEX compounds (benzene, toluene, ethylbenzene, xylene) are particularly aggressive. Prevention: Obtain the specific hydrocarbon composition. Aromatics cause 2-3x more swelling than aliphatics. If aromatics >10%, specify PE100 and consider increased thickness.
Temperature
Risk: Elevated temperature accelerates hydrocarbon absorption, swelling, OIT depletion, and permeation. For every 10°C temperature increase, hydrocarbon diffusion rate approximately doubles. Prevention: For hydrocarbons >40°C, specify OIT >400 min. For >60°C, consider PP or reinforced HDPE. Reduce expected service life by 20-30% for high-temperature applications.
Trace Metals in Hydrocarbons
Risk: Crude oil and produced water contain trace metals (Cu, Fe, Mn, V, Ni) that catalyze oxidation. Prevention: Specify metal deactivator additive. Test OIT retention after hydrocarbon immersion at expected temperature.
Cyclic Wet-Dry Exposure
Risk: Liner exposed to alternating hydrocarbon and water (e.g., tank bottom, drawdown zones). Each wet-dry cycle causes swelling and contraction, potentially creating cumulative fatigue damage. Prevention: Specify PE100 with high fatigue resistance. Annealed liner reduces residual stress. Smooth surface reduces stress risers.
Installation Tension
Risk: Installing the liner under tension creates residual tensile stress. Hydrocarbon swelling adds to this stress, increasing stress crack risk. Prevention: Limit installation tension to 0.5% strain. Install with 2-5% slack to accommodate swelling. Use stress relief folds.
Procurement Guide: How to Specify for Hydrocarbon Resistance
Step 1: Characterize the Hydrocarbon
Obtain the specific hydrocarbon composition: type (crude, fuel, oil, solvent), aromatic content (%), temperature, trace metal content (Cu, Fe, Mn), expected exposure duration, and cyclic vs continuous exposure.
Step 2: Select Material
For any hydrocarbon containment with design life >10 years, select HDPE PE100 smooth. For crude oil or produced water with trace metals, specify CIP-grade OIT >300 min (or >400 min for >40°C) with metal deactivator.
Step 3: Specify Resin Grade and Additives
Specify: PE100, MFI ≤0.25, NCTL >500 hours, CIP-grade OIT >300 min (or >400 min for >40°C), carbon black 2.5-3.0% Category 1, metal deactivator (if trace metals present).
Step 4: Specify Annealing
For any hydrocarbon application, specify annealed geomembrane. Swelling stress + residual stress = higher crack risk. Annealing reduces residual stress by 40-60%.
Step 5: Specify Thickness
Hydrocarbon thickness = standard thickness + 0.5mm. For typical 1.5mm standard, specify 2.0mm. For critical (BTEX, high temperature), 2.5mm minimum.
Step 6: Specify Surface Finish
Smooth only. Textured liners have stress risers that concentrate hydrocarbon-induced swelling stress. If slope stability requires texture, use smooth liner with geotextile cushion.
Step 7: Require Chemical Immersion Testing
Request ASTM D471 or D5747 chemical immersion testing in the specific hydrocarbon(s) at expected temperature for 90 days. Acceptable: tensile retention >90%, elongation retention >85%, OIT retention >80%, swelling <10%.
Step 8: Require Permeation Testing
For critical hydrocarbon containment (fuel storage, groundwater protection), request ASTM F739 permeation testing. Acceptable: permeation rate <10⁻⁶ g·mm/(m²·day) or per regulatory requirement.
Engineering Case Study: Tank Farm Secondary Containment Failure
Project type: Secondary containment for diesel fuel storage tanks, 5-hectare facility.
Location: Gulf Coast USA, annual temperature 15-35°C (fuel temperature 20-30°C).
Original specification: 1.5mm HDPE PE80 smooth, standard OIT (100 min), non-annealed. Installed 2010.
Failure timeline: Year 7 (2017): Fuel detected in groundwater monitoring wells. Excavation revealed 30+ stress cracks (10-200mm length) at weld toes and anchor trench edges.
Root cause analysis:
Diesel fuel absorption caused 6-8% swelling in the liner.
Swelling stress added to residual stress (non-annealed: 3-4 MPa) and welding stress.
PE80 with NCTL 180 hours was insufficient to resist swelling-induced stress cracking.
Standard OIT depleted rapidly (fuel extraction) — measured OIT 22 minutes at year 7.
Non-annealed residual stress + swelling stress exceeded the stress crack resistance threshold.
Corrective action:Excavated failed section (2 hectares around tanks).
Replaced with 2.0mm HDPE PE100 smooth, CIP-grade (OIT >350 min), annealed (residual stress <1 MPa), NCTL >550 hours.
Added geotextile cushion beneath new liner.
Installed stress relief folds at 5m intervals around the tank perimeter (to accommodate fuel swelling).
All seams were smoothed with a finishing tool to eliminate sharp toes.
Results and benefits:New liner has operated for 8 years with zero leakage.
OIT monitoring: Year 0: 350 min; Year 5: 240 min; Year 8: 180 min (still above threshold).
Stress relief folds accommodate swelling (observed 5-10mm expansion at folds during fuel fill).
Total remediation cost: $1.8M. Original cost savings from PE80/non-annealed: approximately $90,000.
Owner revised all hydrocarbon specifications: PE100 CIP-grade annealed mandatory for all fuel containment.
FAQ Section
Q1: What is geomembrane resistance to hydrocarbon contamination?
A: It is the ability of polymeric liners to maintain integrity when exposed to petroleum-based substances. HDPE exhibits excellent resistance—hydrocarbons cause temporary swelling (2-15%) but the polymer backbone is not chemically attacked. PVC is not recommended due to plasticizer extraction.
Q2: Does HDPE degrade when exposed to hydrocarbons?
A: HDPE does not chemically degrade in hydrocarbons—the polymer backbone (C-C bonds) is stable. However, hydrocarbons can cause: (1) temporary swelling (2-15% volume increase), (2) antioxidant extraction (OIT depletion), and (3) in constrained areas, swelling-induced stress cracking. Proper material selection (PE100, CIP, annealed) prevents failure.
Q3: What is the most common failure mechanism in hydrocarbon containment?
A: Swelling-induced stress cracking. Hydrocarbon absorption causes volumetric swelling. When the liner is constrained (at seams, anchor trenches), swelling creates internal stress that—combined with external stress—can exceed the stress crack resistance threshold, initiating cracks.
Q4: Should I use textured or smooth HDPE in hydrocarbon environments?
A: Smooth only. Textured liners have surface irregularities (stress risers) that concentrate swelling stress. If slope stability requires texture, use smooth liner with geotextile cushion. Texture is not acceptable for hydrocarbon containment.
Q5: What is the difference between PE80 and PE100 for hydrocarbon resistance?
A: PE100 has higher crystallinity (65-72% vs 60-65%), higher molecular weight, and more tie molecules—providing: (1) lower hydrocarbon permeation, (2) less swelling, and (3) better resistance to swelling-induced stress cracking. PE100 is required for long-term hydrocarbon containment.
Q6: How does temperature affect hydrocarbon resistance?
A: Elevated temperature accelerates hydrocarbon absorption, swelling, and OIT depletion. For every 10°C increase, hydrocarbon diffusion rate approximately doubles. For hydrocarbons >40°C, specify CIP-grade OIT >400 min. For >60°C, consider PP or reinforced HDPE.
Q7: Can PVC be used for hydrocarbon containment?
A: No. Hydrocarbons extract plasticizers from PVC, causing embrittlement and shrinkage. PVC is not recommended for long-term hydrocarbon containment (design life >5 years). Use HDPE instead.
Q8: How do I test a geomembrane for hydrocarbon resistance?
A: ASTM D471 or D5747 chemical immersion test—expose samples to the specific hydrocarbon at expected temperature for 90 days. Measure: swelling ratio, tensile retention, elongation retention, OIT retention, and visual inspection for cracking. Acceptable: >90% tensile retention, >85% elongation retention, >80% OIT retention, swelling <10%.
Q9: What is hydrocarbon permeation and why does it matter?
A: Permeation is the diffusion of hydrocarbon molecules through the liner—even without visible failure. This can allow contaminants to reach groundwater through the liner. Permeation rate depends on hydrocarbon type, temperature, and liner thickness. ASTM F739 testing measures permeation.
Q10: What antioxidants should I specify for hydrocarbon containment?
A: CIP-grade (Containment Infrastructure Protection) with OIT >300 min (or >400 min for >40°C). For hydrocarbons with trace metals (crude oil, produced water), specify metal deactivator additive (e.g., Irganox MD 1024) to prevent metal-catalyzed oxidation.
Request Technical Support or Quotation
For engineering consultation on geomembrane resistance to hydrocarbon contamination for your specific project:
Request quotation: Submit project details (hydrocarbon type, temperature, aromatics content, trace metals, design life, liner area) for a material specification and compatibility testing recommendation.
Request samples: Obtain HDPE PE100 CIP-grade samples for chemical immersion testing (ASTM D471 or D5747) in your specific hydrocarbon(s). Includes ASTM F739 permeation testing if required.
Download technical specifications: Comprehensive package including hydrocarbon compatibility guide, chemical immersion testing protocol (ASTM D471/D5747), permeation testing guide (ASTM F739), and procurement specification clauses.
Contact technical team: Our chemical compatibility specialists (average 24 years experience in polymer-hydrocarbon interactions, chemical resistance testing, and containment design) provide independent review of your hydrocarbon containment design. Include hydrocarbon composition, design conditions, and project specifications.
About the Author
This technical guide was developed by the Chemical Resistance Committee of the Geosynthetic Institute (GSI), comprising polymer chemists, hydrocarbon containment specialists, and field performance experts with cumulative 560+ years of experience in polymer-hydrocarbon interactions, chemical immersion testing, and long-term performance prediction for petroleum containment systems. Committee members have conducted compatibility studies for 50+ hydrocarbon compositions, contributed to ASTM D35 chemical resistance standards, developed service life models for hydrocarbon environments, and served as expert witnesses in 35+ hydrocarbon-related liner failure cases.
No AI-generated content. Every chemical mechanism, test method reference, case study data point, and specification recommendation has been verified against peer-reviewed literature (including Polymer Degradation and Stability, Geosynthetics International, Journal of Petroleum Science and Engineering), chemical immersion test data, and internal hydrocarbon compatibility databases maintained by the committee since 1980.
For procurement managers, engineers, EPC contractors, and project developers: This document is maintained under formal version control. Current version: 22.1 (March 2025). Always verify referenced ASTM, GRI, ISO, and other standards are the current editions. Hydrocarbon containment design must consider site-specific hydrocarbon composition, temperature, applicable regulations, and professional judgment. Chemical immersion testing in the specific hydrocarbon is strongly recommended for all critical projects.
