A REVIEW OF CORROSION–RELATED PROCESS SAFETY HAZARDS IN OIL AND GAS FACILITIES: MECHANISMS, CONSEQUENCES, AND MITIGATION STRATEGIES

International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 239 A REVIEW OF CORROSION–RELATED PROCESS SAFETY HAZARDS IN OIL AND GAS FACILITIES: MECHANISMS, CONSEQUENCES, AND MITIGATION STRATEGIES Ohimor, Evuensiri Onoghwarite 1 , Adebayo, Ayodeji Temitope 2 , Olaniyan, Adebukola Opeyemi 3 , Emeko, Abugewa Harrison 4 , Emeteveke, Elijah Aghogho 5 , Mukoro, Amos 6 1 Department of Chemical Engineering, Federal University of Petroleum Resources, Effurun, Nigeria, +2348033888418, ohimor[email protected] 2 Department of Chemical Engineering, Federal University of Petroleum Resources, Effurun, Nigeria, +2347063553800, [email protected] 3 Department of Chemical Engineering, Federal University of Petroleum Resources, Effurun, Nigeria, +2348064478010, [email protected] 4 Department of Chemical Engineering, Federal University of Petroleum Resources, Effurun, Nigeria, +2349062167747, [email protected] 5 Department of Chemical Engineering, Federal University of Petroleum Resources, Effurun, Nigeria, +2348036993459, [email protected] 6 Department of Chemical Engineering, Federal University of Petroleum Resources, Effurun, Nigeria, +2348126971428, [email protected] Internaonal Journal of Emerging Trends in Engineering and Development Available online on hp://www.rspublicaon.com/ijeted/ijeted_index.htm ISSN 2249-6149 Cite This Paper: Ohimor, Evuensiri Onoghwarite, Adebayo, Ayodeji Temitope, Olaniyan, Adebukola Opeyemi, Emeko, Abugewa Harrison, Emeteveke, Elijah Aghogho and Mukoro, Amos (2025). "PA REVIEW OF CORROSION–RELATED PROCESS SAFETY HAZARDS IN OIL AND GAS FACILITIES: MECHANISMS, CONSEQUENCES, AND MITIGATION STRATEGIES". INTERNATIONAL JOURNAL OF EMERGING TRENDS IN ENGINEERING AND DEVELOPMENT (IJETED), vol. 15, no. 6, 2025, pp. 239-274. DOI: https://dx.doi.org/10.5281/zenodo.17930937 International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 240 ABSTRACT Corrosion in oil and gas facilities presents significant safety, environmental, and economic challenges, necessitating advanced mitigation strategies to ensure operational integrity. This comprehensive review systematically examines corrosion mechanisms, including Sweet (CO 2 ), Sour (H 2 S), Chloride induced-stress corrosion cracking (SCC), Oxygen corrosion, Galvanic, Crevice and microbiologically influenced corrosion (MIC), Corrosion under insulation (CUI) and their consequences, such as leaks, explosions, and structural failures, while evaluating economic impacts like production downtime and regulatory penalties, and environmental impact. Through a synthesis of literature published in the domain of Oil and Gas production, processing, transportation, and storage, we identify critical gaps in current corrosion management practices, particularly in aging infrastructure and extreme operating environments. Recent advancements in corrosion-resistant alloys (CRAs), smart coatings, and green inhibitors demonstrate improved performance, complemented by emerging technologies such as real-time monitoring, machine learning-based prediction models, and risk-based inspection (RBI) methodologies. Despite progress, implementation challenges persist, highlighting the need for integrated, data-driven corrosion management systems. This review concludes with actionable recommendations for optimizing corrosion management, enhancing asset longevity, and improving process safety in hydrocarbon operations through sustainable, predictive approaches. Keywords: corrosion mitigation, oil and gas, process safety, predictive maintenance, materials science, risk management .Corresponding Author: Ohimor E.O. INTRODUCTION The oil and gas industry operates in inherently corrosive environments due to the presence of water, acids, salts, and aggressive gases such as H₂S and CO₂ [1]. Corrosion-induced degradation of critical infrastructure, including pipelines, storage tanks, and processing equipment, poses severe safety risks, with potential for catastrophic failures that endanger human life, the environment, and economic stability [2]. Corrosion not only erodes pipelines, wells, and processing equipment but also lead to incidents such as leaks, ruptures, and explosions. Historical cases like the 2010 Deepwater Horizon blowout illustrates the catastrophic potential of corrosion. Corrosion remains one of the most persistent and costly challenges in the hydrocarbon sector, contributing substantially to process safety incidents, equipment failures, and environmental contamination. According to the National Association of Corrosion Engineers (NACE), the global annual cost of corrosion in oil and gas exceeds $2.5 trillion, with a significant portion attributed to unplanned shutdowns, emergency maintenance, and safety-related liabilities [3]. Process safety management (PSM), as mandated by regulations like OSHA 1910.119, integrates corrosion control through elements such as process hazard analysis (PHA), mechanical integrity (MI), and International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 241 management of change (MOC), ensuring proactive risk mitigation [4]. Corrosion risk is increased by operational demands of harsh environments, such as deepwater drilling, sour gas fields, and aging infrastructure, coupled with the use of more corrosive feedstocks, such as high-sulfur crude and enhanced oil recovery (EOR) techniques like water injection and CO₂ flooding, [5]. Despite advancements in materials science and protective technologies, significant gaps remain in the implementation of holistic corrosion management systems that integrate real-time monitoring, predictive analytics, and risk-based integrity protocols [6]. This review systematically examines corrosion-related process safety hazards in oil and gas facilities, with the following objectives: to analyze key corrosion mechanisms and their contributing factors; to evaluate the safety, economic, and environmental consequences of corrosion failures; to assess current and emerging mitigation strategies; and to identify future research directions and implementation frameworks. By synthesizing recent literature, this work aims to provide a comprehensive, up-to-date resource for researchers, engineers, and safety managers seeking to enhance asset integrity and operational reliability in corrosive hydrocarbon environments. The devastating appearance in fig 1, shows the inherent risk in refinery operations. Fig. 1: Examples of some refinery accidents caused by corrosion failure. (a) Golden Eagle Refinery, (b) Richmond Refinery, (c), and (d) Chevron Refinery [7]. International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 242 CORROSION MECHANISMS IN OIL AND GAS FACILITIES Corrosion in oil and gas facilities occurs through various mechanisms, each driven by specific environmental conditions, material properties, and operational factors [8]. Understanding these mechanisms is crucial for predicting failure modes, implementing effective mitigation strategies, and ensuring process safety. The most prevalent forms of corrosion in the industry include sweet corrosion, Sour corrosion, chloride-induced stress corrosion cracking (SCC), galvanic corrosion, Crevice corrosion, Oxygen corrosion, Corrosion under insulation (CUI), and microbiologically influenced corrosion (MIC) [9]. Recent research has provided deeper insights into these mechanisms, particularly in harsh environments such as deepwater production, sour gas fields, and aging infrastructure. 1. Sweet Corrosion (CO₂ Corrosion) Sweet corrosion, induced by CO₂ in the absence of significant H₂S, is a dominant degradation mode in upstream oil and gas facilities, affecting carbon steel pipelines, well casings, and separators. It manifests as uniform thinning, pitting, or mesa-like attacks, particularly in high-velocity flows, and is intensified in environments with CO₂ partial pressures above 0.3 bar. In natural gas transmission lines, it accounts for widespread failures, with rates peaking at temperatures between 60-80°C due to enhanced kinetics. Recent studies highlight its role in enhanced oil recovery (EOR) operations using densephase CO₂, where it impacts both the injection and production sides [10]. The sweet corrosion mechanism initiates with the dissolution of CO₂ in aqueous phases to form carbonic acid, which dissociates to provide protons for cathodic reduction, thereby driving anodic iron dissolution. This leads to the formation of iron carbonate (FeCO₃) scales, which can be protective in low flow conditions but erode under turbulence, exposing fresh metal and accelerating localized corrosion [10]. Factors such as pH (typically 4-6), flow shear stress, and organic acids further influence scale stability and corrosion rates. In downhole environments, sweet corrosion poses a threat to tubular integrity, often exacerbated by CO₂ from reservoir gases [11]. The mechanism of the electrochemical reaction describing sweet corrosion is shown with Eqn (1-5). CO₂ + H₂O ⇌ H₂CO₃ (1) International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 243 H₂CO₃ ⇌ H⁺ + HCO₃⁻; HCO₃⁻ ⇌ H⁺ + CO₃²⁻ (2) Fe → Fe²⁺ + 2e⁻ (anodic) (3) 2H⁺ + 2e⁻ → H₂ or 2H₂CO₃ + 2e⁻ → H₂ + 2HCO₃⁻ (cathodic) (4) Fe + H₂CO₃ → FeCO ₃ + H₂ (overall) (5) Fig 2: Illustration of sweet corrosion [10] Sweet corrosion poses significant PSM risks, including pipeline leaks and explosions due to thinned walls and pitting, potentially releasing hydrocarbons or CO₂ under pressure. Effective PSM involves DMRs to identify CO₂ hotspots, corrosion inhibitors for scale control, and real-time monitoring to prevent failures. Material upgrades to corrosionresistant alloys (CRAs) and adherence to OSHA guidelines enhance safety, reducing incident rates in EOR and transmission systems. Case studies show that proactive air monitoring and inhibitor programs mitigate risks, ensuring operational integrity. 2. Sour Corrosion (H₂S Corrosion) Sour corrosion, triggered by H₂S concentrations exceeding 100 ppm, is a severe threat in sour gas fields, refineries, and pipelines, causing pitting, sulfide stress cracking (SSC), and hydrogen-induced cracking (HIC). It introduces toxicity hazards and material embrittlement, prevalent in 40% of global reserves, and necessitates sour-service materials International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 244 compliant with NACE MR0175. Recent reviews emphasize its synergy with CO₂ in mixed environments, amplifying corrosion in wet gas systems [12]. H₂S dissociates to HS⁻ and S²⁻ ions, facilitating cathodic hydrogen evolution while poisoning recombination, thus promoting atomic hydrogen diffusion into the steel lattice, leading to blistering and cracking (eqn 6-10). Iron sulfides such as mackinawite form as non-adherent films, which spall and expose underlying metal, accelerating localized attacks in low-pH (<5) conditions. Challenges include hydrate formation and equipment fouling in sour fields. Material selection focuses on low-hardness steels to resist SSC. H₂S ⇌ H⁺ + HS⁻; HS⁻ ⇌ H⁺ + S²⁻ (6) Fe → Fe²⁺ + 2e⁻ (7) 2H⁺ + 2e⁻ → 2H → H₂ (poisoned by H₂S) (8) Fe²⁺ + HS⁻ → FeS + H⁺ (9) Fe + H₂S → FeS + H₂ (10) Sour corrosion heightens PSM concerns through toxicity, flammability, and explosive risks from H₂S releases, alongside equipment failures like cracking [4]. Management strategies include H₂S scavengers, real-time corrosion monitoring, and inherently safer designs like ventilation to minimize exposure. Compliance with aqua standards and NACE guidelines ensures safe handling, reducing incidents in sour processing facilities Fig. 3: Sour corrosion (https://amarineblog.com/2020/10/24/what-is-sour-service-in-oilgas) International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 245 3. Microbial-Induced Corrosion (MIC) in Oil and Gas Facilities MIC affects oil and gas infrastructure like pipelines, storage tanks, and injection systems, where microbes in water or hydrocarbons accelerate corrosion, causing pitting and leaks. Prevalent in low-flow areas or seawater injection lines, it leads to severe under-deposit corrosion in crude oil transport, often involving SRB in anaerobic conditions. It contributes to major failures in offshore platforms and refineries [13]. Biofilms form on surfaces, creating anodic sites via metabolite production (e.g., H₂S from SRB) or electron transfer, enhancing pitting in pipelines. In oilfields, nutrients from hydrocarbons fuel microbial growth, leading to differential aeration and acidification under deposits. Flow, temperature, and pH influence severity, requiring biocides for control [14]. The mechanism of the reactions is described in Eqn (11-15) Anodic: Fe → Fe²⁺ + 2e⁻ (11) Cathodic (SRB): SO₄²⁻ + 9H⁺ + 8e⁻ → HS⁻ + 4H₂O (12) Sulfide: Fe²⁺ + HS⁻ → FeS + H⁺ (13) Overall: 4Fe + SO₄²⁻ + 4H₂O → 3Fe(OH)₂ + FeS + 2OH⁻ (14) MIC increases PSM risks through accelerated pitting and hidden failures, potentially leading to leaks in critical infrastructure like pipelines. Management includes biocides, pigging for cleaning, and accurate monitoring methodologies to assess MIC threats. Riskbased models and prevention programs ensure integrity, reducing destructive impacts in Oil and gas operations Fig. 4: Illustration of the Mechanism of MIC [13] International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 246 4. Chloride Stress Corrosion Cracking (CSCC) CSCC afflicts austenitic stainless steels in chloride-laden environments, such as seawatercooled exchangers and offshore platforms, resulting in transgranular cracking under tensile stress at temperatures >50°C. It often initiates from pits or crevices and is a leading cause of failures in corrosion-resistant alloys (CRAs). Corrosion under insulation (CUI) exacerbates it in insulated lines. Chlorides adsorb and disrupt passive oxide films, leading to localized anodic dissolution at crack tips, augmented by hydrogen embrittlement [15]. Three stages include initiation, propagation, and failure, influenced by stress and environment. Duplex steels offer better resistance but are not immune as described by Eqn (15-18). Cl⁻ + M → MCl (film breakdown) (15) Fe → Fe²⁺ + 2e⁻ (16) O₂ + 2H₂O + 4e⁻ → 4OH⁻ (17) H⁺ + e⁻ → H (embrittlement) (18) Fig. 5: Chloride-induced stress corrosion cracking [15] International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 247 5. Oxygen Corrosion Oxygen corrosion arises from dissolved oxygen in water systems, affecting boilers, injection lines, and pipelines, leading to rust formation and pitting where oxygen ingress occurs. It is a primary concern in upstream operations with aerated fluids, often synergizing with other corrosives. Dehydration and scavengers are standard controls. Differential aeration establishes anodic sites in oxygen-poor zones, with cathodic reduction in aerated areas, forming ferric hydroxides. Ingress via pumps or incomplete deaeration accelerates pitting under deposits. Rates increase in neutral-alkaline pH and higher temperatures [16]. Fe → Fe²⁺ + 2e⁻ (19) O₂ + 2H₂O + 4e⁻ → 4OH⁻ (20) Fe²⁺ + 2OH⁻ → Fe(OH) ₂ (21) 4Fe(OH)₂ + O₂ + 2H₂O → 4Fe(OH) ₃ (22) Oxygen corrosion compromises PSM by causing leaks and spills, heightening explosion risks in hydrocarbon systems. Strategies include oxygen scavengers, deaeration, and monitoring to prevent ingress, aligned with OSHA PSM for mechanical integrity. Comprehensive programs mitigate hazards, ensuring safe processing. Fig. 6: Oxygen corrosion [16] International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 254 distributed fiber optic sensors are transforming maintenance practices by enabling continuous corrosion monitoring [31]. However, implementation challenges, including high costs and workforce training gaps, remain barriers to widespread adoption. Table 1: Showing the primary environment, contributing factors and mitigation strategies for different corrosion type 2.3. CONSEQUENCES OF CORROSION IN OIL AND GAS FACILITIES The safety consequences of corrosion in oil and gas facilities remain severe and multifaceted. While engineering solutions continue to advance, the persistent occurrence of corrosion-related incidents underscores the need for improved safety management practices that specifically address corrosion risks. 2.3.1. SAFETY HAZARDS Corrosion-induced failures in oil and gas facilities present severe safety hazards that can escalate into catastrophic incidents. Recent studies (2020-2025) have demonstrated that corrosion remains a root cause in approximately 25-30% of major process safety incidents in the hydrocarbon Mechanism Primary Environments Key Contributing Factors Common Detection Methods Typical Mitigation Strategies Uniform Corrosion Acidic, O₂-rich fluids CO₂, temperature, flow rate Ultrasonic testing, weight loss Inhibitors, coatings, CRAs Pitting Corrosion Chloride-rich, stagnant zones Cl⁻, microbes, passive film defects ENA, 3D microscopy, visual inspection Cathodic protection, alloy upgrade SCC Sour gas, chloridecontaining H₂S, Cl⁻, tensile stress, temperature NDT, acoustic emission Material selection, stress relief Galvanic Corrosion Mixed-metal assemblies, seawater Potential difference, electrolyte conductivity Potential mapping, visual inspection Dielectric isolation, CP ErosionCorrosion High-velocity multiphase flows Sand content, flow velocity, turbulence CFD modeling, thickness monitoring Hard coatings, flow control MIC Stagnant water, biofilms SRB/APB presence, nutrient availability DNA sequencing, biofilm sensors Biocides, cleaning, coatings International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 255 industry [3]. The primary safety hazards manifest in three critical forms: leaks and spills, structural failures, and human casualties. 1. Leaks and Spills: Leading to Fires, Explosions, and Toxic Releases Corrosion-related loss of containment represents the most immediate and dangerous safety hazard in oil and gas operations. Thinning pipelines or vessel walls due to uniform corrosion, or localized breaches from pitting corrosion, can lead to hydrocarbon releases that may ignite, resulting in devastating fires and explosions [32]. The 1988 Piper Alpha disaster, where corrosion-induced gas leaks caused a catastrophic explosion killing 167 workers, remains a stark reminder of these risks. Recent incidents, such as the 2021 Pemex offshore platform fire attributed to corroded gas lines [33] demonstrate that this hazard persists despite technological advancements. In sour gas facilities, additional risks emerge from toxic H₂S releases, which can cause immediate asphyxiation and pose long-term environmental health risks [34]. 2. Structural Failures: Collapse of Storage Tanks or Pipeline Ruptures Progressive corrosion damage can compromise structural integrity, leading to sudden and catastrophic failures. Storage tank collapses due to bottom plate corrosion and pipeline ruptures from stress corrosion cracking (SCC) represent particularly severe scenarios. The 2010 San Bruno pipeline explosion, caused by external corrosion and inadequate inspections, resulted in 8 fatalities and highlighted systemic safety management failures [35]. Recent research indicates that aging infrastructure presents growing risks, with studies showing a 40% increase in corrosion-related incidents in facilities operating beyond their design life [36]. Subsea systems face additional challenges, where corrosion-fatigue interactions can lead to riser failures with severe environmental consequences [37]. 3. Human Casualties: Worker Injuries/Fatalities Due to Sudden Equipment Failures The human cost of corrosion-related incidents remains alarmingly high. Sudden equipment failures caused by corrosion mechanisms such as erosion-corrosion in choke valves or microbiologically International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 256 influenced corrosion (MIC) in firewater systems have resulted in numerous worker injuries and fatalities [38]. A 2022 study of offshore accidents revealed that 35% of maintenance-related fatalities occurred during interventions on corroded equipment [39]. The psychological impact on workforces following corrosion-related incidents also contributes to safety culture degradation, creating secondary risks [40]. Recent advances in predictive analytics and integrity management systems aim to reduce these risks, but implementation challenges persist, particularly in remote operations. Table 2: The chronology of accidents in oil and gas facilities in Europe and America Incident Year Location Primary Corrosion Mechanism Safety Impact Economic Impact (USD) Author(s) Piper Alpha Disaster 1988 UK CO₂ corrosion in gas risers 167 fatalities, explosion $3.4 billion [39] San Bruno Pipeline Explosion 2010 USA External SCC 8 fatalities, major fire $1.6 billion [35] Philadelphia Energy Solutions Refinery Explosion Philadelphia, Pennsylvania, USA 2019 Localized corrosion A corroded carbon steel elbow in a hydrofluoric acid unit ruptured due to high corrosion rates and insufficient monitoring Massive explosion and fire; release of hazardous materials; permanent refinery closure; no fatalities but injuries [44] Pemex Offshore Platform Fire 2021 Mexico MIC in gas pipelines 7 fatalities, platform destroyed $500 million [41] Alberta Oil Sands Spill 2023 Canada Erosion-corrosion 5,000-barrel spill, ecological damage $300 million [42] International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 257 Table 3: Corrosion–induced accidents in the Oil and Gas Facilities in Africa Incident Locaon Year Primary Corrosion Mechanism Root Causes Consequences Economic Impact (USD) References Bodo Creek Pipeline Leak Bodo Creek, Niger Delta, Nigeria 2012 External corrosion Aging infrastructure, lack of timely repairs Oil leak into the creek; environmental degradation, affected fishing Unknown [62] Bonny Well Flowline Spill Ererekiri Okolo Launch, Niger Delta, Nigeria 2014 Corrosion (operational) Equipment failure, delayed investigation Minimal spill (0.03 barrels), but indicative of systemic issues; local contamination Unknown [62] Diebu CreekNun River Pipeline Spill Onyoma, Niger Delta, Nigeria 2014 Pitting corrosion (suggested) Possible operational failure misclassified as sabotage Large spill of 367 barrels; pollution of the river and creeks Unknown [62] Ogoda/Brass Pipeline Spill Bayelsa State, Niger Delta, Nigeria 2015 Induced corrosion (external) Third-party interference or poor maintenance Spill of 1 barrel; local environmental impact Unknown [62] Obiafu Flowline Spill Obiafu, Niger Delta, Nigeria 2016 External corrosion Negligence, aging pipes Spill of 3 barrels; repeated incidents on the same line Unknown [62] Limbe Refinery Explosion Limbe, Cameroon 2019 Localized corrosion Failed elbow due to unexpected high corrosion rates, poor monitoring Fire and explosion; shutdown of refinery for up to 12 months; no deaths reported $600 million in property damage [61] FPSO Trinity Spirit Ukpokiti Terminal, OML 108 2022 uniform and localized corrosion, MIC Aging infrastructure, lack of maintenance and integrity management Total loss of the FPSO vessel, loss of 40,000 barrels of crude, with environmental contamination. 7 fatalities 2 million bbl storage capacity and 22,000 bpd production facility. [60] International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 258 3.2 ECONOMIC AND ENVIRONMENTAL IMPACT OF CORROSION The financial repercussions of corrosion in hydrocarbon facilities are staggering, with unplanned shutdowns representing one of the most significant cost factors. In March 2019, a fire at a US tank farm caused approximately $125 million in property damage. The incident was severe, leading to the destruction of at least 12 of the 15 tanks at the facility, as a result of chloride-induced pitting corrosion [43]. Maintenance expenditures present another major economic burden, with African refineries alone spending approximately $60 million annually on corrosion-related repairs [47]. Regulatory penalties have become increasingly severe, exemplified by Shell's $50 million fine in Nigeria for 2023 spillage incidents originating from corroded pipelines [45]. Environmental damage from corrosion-induced spills creates long-term ecological liabilities, particularly in sensitive delta regions. Nigeria's Niger Delta has absorbed over 1.5 million barrels of spilled hydrocarbons since 2000 due primarily to pipeline corrosion [46], while the 2023 Alberta bitumen spill required $300 million in cleanup costs after erosion-corrosion breached a slurry pipeline [42]. These incidents collectively highlight the urgent need for more robust corrosion management strategies that address both immediate safety concerns and long-term sustainability challenges. Recent technological developments in predictive analytics and advanced materials offer promising solutions, though their widespread implementation across global operations remains inconsistent [48]. The industry must prioritize integrated corrosion prevention frameworks that simultaneously mitigate safety risks, reduce financial losses, and minimize environmental damage to ensure sustainable operations moving forward. CORROSION MITIGATION STRATEGIES IN OIL AND GAS FACILITIES 4.1. Material Selection and Design The strategic selection of construction materials represents a fundamental approach to corrosion mitigation in hydrocarbon processing environments. Recent industry practice has demonstrated the superior performance of corrosion-resistant alloys (CRAs) in aggressive service conditions, particularly duplex stainless steels (UNS S32205/S32750) and nickel-based alloys (UNS N06625) International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 259 for sour gas applications containing hydrogen sulfide [49]. The American Petroleum Institute's API RP 939-C provides essential material selection guidelines for such challenging environments, specifying threshold limits for H₂S partial pressures and chloride concentrations [34]. Modern engineering design incorporates computational fluid dynamics (CFD) modeling to optimize flow patterns, with Zhang et al. [26] demonstrating 40-60% reductions in flow-assisted corrosion through elimination of stagnant zones and flow disturbances. These material and design strategies form the primary defense against corrosion degradation in oil and gas infrastructure. 4.2. Protective Coatings and Cathodic Protection Surface protection systems provide critical secondary barriers against corrosion in petroleum facilities. Epoxy-phenolic coatings have established industry preference for submerged service, with documented performance exceeding 15 years in offshore applications [18]. For particularly aggressive splash zone exposures, thermal-sprayed aluminum (TSA) coatings offer enhanced protection through their unique self-healing properties when damaged [36]. Cathodic protection systems require precise potential control, with the NACE SP0169 standard recommending maintenance between -0.85V to -1.1V versus Cu/CuSO4 reference electrode to balance protection effectiveness against hydrogen embrittlement risks [3]. Recent field implementations of solarpowered impressed current systems have extended reliable corrosion protection to remote installations [50], demonstrating the ongoing evolution of these critical protection technologies. 4.3. Chemical Inhibitors and Biocides Chemical treatment programs provide essential internal corrosion control through multiple mechanisms of action. Filming amine inhibitors has demonstrated particular effectiveness in sweet corrosion environments, with Jarrah et al. [51] documenting a 90% reduction in CO₂ corrosion rates at concentrations as low as 50 ppm through the the formation of protective surface films. For microbiologically influenced corrosion (MIC) control, tetrakis hydroxymethyl phosphonium sulfate (THPS) biocides maintain effectiveness against sulfate-reducing bacteria at concentrations of 100-150 ppm [52]. The field is experiencing growing interest in environmentally sustainable International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 260 alternatives, with plant-derived inhibitors demonstrating 85-92% efficiency in laboratory evaluations while addressing increasing regulatory pressures [53]. These chemical solutions complement material and coating strategies to provide comprehensive corrosion defense. 4.4. Monitoring and Inspection Technologies Advanced diagnostic technologies enable unprecedented precision in corrosion detection and remaining life prediction. Phased array ultrasonic testing systems now achieve wall thickness measurements with ±0.1 mm accuracy, revolutionizing integrity assessments [54]. In-line inspection tools have evolved to combine multiple technologies, with modern smart pigs integrating magnetic flux leakage (MFL) and electromagnetic acoustic transducers (EMATs) for comprehensive pipeline condition monitoring [41]. Machine learning applications are transforming corrosion prediction, with Sanni et al. [55] reporting 92% accuracy in remaining life forecasts through analysis of historical inspection data. These technological advances provide the critical data foundation for effective integrity management programs. 4.5. Industry Standards and Best Practices Standardized frameworks guide effective implementation of corrosion control measures across the industry. The API 570 standard establishes essential requirements for piping inspection, while NACE SP0169 provides the technical basis for cathodic protection system design [3]. ISO 155891 offers comprehensive guidelines for pipeline integrity management systems [56]. The adoption of risk-based inspection (RBI) methodologies has demonstrated particular value, with DNV [41] documenting 25-30% cost reductions through optimized inspection planning. These standards and practices collectively form the foundation for effective corrosion management programs in hydrocarbon facilities. 5. Future Trends and Research Directions Emerging technologies are reshaping corrosion mitigation approaches in the petroleum industry. Graphene-enhanced coatings represent a significant materials advancement, with Al-Sayegh et al. International Journal of Emerging Trends in Engineering and Development Issue 15, Vol.6, 2025 Available online on http://www.rspublication.com/ijeted/ijeted_index.htm ISSN 2249-6149 DOI: 10.5281/zenodo.17930937 Original Article @2025 RS Publicaon, rspublica[email protected] 261 [57] reporting 99% barrier efficiency in laboratory evaluations through enhanced molecular barrier properties. Artificial intelligence applications are revolutionizing corrosion prediction, with Huang et al. [58] achieving 94% accuracy in offshore platform corrosion modeling through deep learning algorithms. Self-healing coating technologies are extending service lives by up to 200% through innovative microencapsulation of corrosion inhibitors [59]. These technological developments, combined with growing emphasis on environmentally sustainable solutions, are driving a transformation in corrosion management practices across the oil and gas sector. CONCLUSION Corrosion in oil and gas facilities remains a critical challenge with significant implications for safety, economics, and environmental stewardship. This review has systematically examined corrosion mechanisms, consequences, and mitigation strategies, highlighting both technological advancements and persistent implementation gaps. Corrosion mechanisms are complex and often synergistic, requiring integrated management approaches. Safety incidents continue to occur despite available technologies, underscoring the need for improved inspection regimes and safety cultures. Economic losses from corrosion are substantial, but proactive investment in mitigation yields strong returns. Emerging technologies—including AI, smart coatings, and green inhibitors—offer transformative potential but require further standardization and field validation. To advance corrosion management in the oil and gas industry, we recommend the adoption of predictive integrity management, shifting from reactive to data-driven, predictive maintenance using RBI, IoT, and machine learning. Investment in sustainable materials should be prioritized, focusing on R&D in corrosion-resistant alloys, green inhibitors, and self-healing coatings. Enhanced training and certification are needed to build workforce competency in corrosion engineering and digital tools. Regulatory frameworks should be strengthened to incorporate new technologies and risk-based approaches. Finally, cross-industry collaboration should be fostered through partnerships between operators, academia, and technology providers. 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