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Results
Abstract In this research lab and field corrosion coupon testing was completed to determine corrosion rates on commonly used Steam Assisted Gravity Drainage (SAGD) metals. This was done to evaluate general corrosion rates, and how they vary with well depth, and operating environment. Based on this analysis and evaluating scale composition a dominating corrosion mechanism was also determined. Lab testing utilized high temperature high pressure autoclaves to allow for field various corrosion rate and characterization measurements to be taken under controlled conditions. Measurements taken include linear polarization resistance, weight loss, and zero resistance annode to determine corrosion rates. Cyclic potentiodynamic polarization and potentiostatic polarization measurements were also obtained to further evaluate a materials effectiveness in preventing pitting corrosion. Materials tested in the lab were 1018 carbon steel, Deloro-40 and Stellite-6 hard facing finishes, TN-55TH, galvanized (GLV) J-55, and K-55. Field coupon testing consisted of installing corrosion coupons at various elevations in the annulus of a producting SAGD well. Coupon materials tested included L-80, J-55, and a GLV-J55+J-55 creviced couple. Analysis consisted of weight loss corrosion rate determination, visual inspections, and x-ray diffraction analysis to determine scale compositions. Field coupons showed corrosion rates decreasing from 0.0178mm/y at the bottom of the well to 0.0145mm/y at higher well elevations. This corresponded to a decrease in iron sulfide (FeS) scale content from the well bottom upwards. Based on the scales composition, operating conditions, and fluids present, it is likely that the scales were formed through the well known solid-state reaction between aqueous H2S and the metal. High average corrosion rates of 0.263mm/y were measured in the lab, compared to a low 0.0183mm/y in field studies. This difference is due to the inhibiting effects of oil in the field which inhibits corrosion rates and the longer field test duration.
- North America > United States > Texas (0.46)
- North America > Canada > Alberta (0.28)
- Geology > Mineral > Sulfide > Iron Sulfide (0.49)
- Geology > Petroleum Play Type > Unconventional Play > Heavy Oil Play (0.46)
Research on Damage Mechanism and Control Measures of Casing and Tubing Corrosion in High-Temperature Fire-Flooding Wells
Long, Hua (Liaohe Oilfield of CNPC) | Sun, Shouguo (Liaohe Oilfield of CNPC) | Zhang, Hongjun (Liaohe Oilfield of CNPC) | Sun, Houli (Liaohe Oilfield of CNPC) | Wang, Lei (Liaohe Oilfield of CNPC) | Liu, Manjun (Liaohe Oilfield of CNPC) | Yu, Xiaocong (Liaohe Oilfield of CNPC)
Abstract With the development of Fire Flooding test, serious corrosion occurred in N80-steel based tubing and casing string and caused severe damages. Wellbore integrity is getting worse, which gives rise to the abandonment of a well section or the whole well. This problem has seriously hampered the fire flooding development. In this research, the component analysis is first applied to the injection and production gas samples of fire flooding well groups, to determine the reaction mechanism and the main corrosion factors of wellbore tubing and casing string. Then, corrosion dynamic simulation experiments are carried out by the first domestic self-developed experimental device of fire flooding corrosion simulation. Corrosion rate of various string pipes under fire flooding conditions with different gas component is simulated and measured quantitatively by using the traditional weight loss method and inductance probe method, aiming to determine the dynamic corrosion degree during the process of fire flooding, and meanwhile the evaluation on the new developed chemical corrosion inhibitor is implemented. For new wells, the anticorrosive materials for casing and tubing is selected according to test results, and the optimal design of completion casing is carried out, to ensure the injection and production wellbore integrity and anticorrosive performance in the development process. For corrosion wells, chemical corrosion inhibitor was developed, and the dynamic simulation and evaluation of corrosion resistance was carried out by means of the fire flooding simulated corrosion model experiment device. The experimental results show that the corrosion rate of N80 steel can be reduced to 0.0687mm/a when the concentration of corrosion inhibitor is 500ppm. This corrosion rate can meet the need of field development. Field tests show that the above measures can effectively prevent or delay the casing and tubing corrosion damage, and extend the service life of fire flooding wells. The fire flooding wellbore corrosion dynamic simulation experimental device has completely changed the current situation of qualitative corrosion evaluation on casing and tubing in the field and realized quantitative evaluation on corrosion damage of tubing and casing. The results of quantitative evaluation provide the basis for optimal design, anticorrosive performance and integrity of wellbore.
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Thermal methods (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
In Situ Mercury Decontamination for Pipeline Decommissioning in the Gulf of Thailand
Chanvanichskul, Chatawut (PTT Exploration and Production Public Company Limited) | Punpruk, Suchada (PTT Exploration and Production Public Company Limited) | Silakorn, Passaworn (PTT Exploration and Production Public Company Limited) | Thammawong, Chanya (PTT Exploration and Production Public Company Limited) | Pornnimitthum, Surapol (PTT Exploration and Production Public Company Limited) | Kumseranee, Sith (PTT Exploration and Production Public Company Limited)
Abstract For offshore decommissioning in the Gulf of Thailand (GoT), Mercury (Hg) has been recognized as a serious contaminant in hydrocarbon streams. Consequently, for PTTEP, as the E&P operator in the Gulf of Thailand, one of the significant environmental and economical issues during decommissioning is the decontamination of Hg in the equipment and pipeline. PTTEP’s decommissioning plan focuses on leaving in situ of subsea pipelines which can be arranged only if Hg contaminated in the pipeline is almost fully cleaned and Hg content is below an acceptable level. Techniques to decontaminate Hg from pipeline and postmonitoring methods are required in the Final Decommissioning Program. Therefore, the research to identify the techniques to measure and remove Hg contents from metal is required. The three innovative steps have been studied including identifying depth of mercury penetration through the pipe surface, developing the technique for in-situ mercury decontamination from the pipeline and finally developing a tool for measuring contaminated Hg content in pipeline before leaving it in situ. According to the study result, the efficiency of the proposed decontamination technique is satisfactory which can remove the major content of Hg in a few hours. In addition, the prototype of tool to measure Hg inside the pipeline was developed and tested successfully. Cleaning process optimization in pilot facilities is currently in progress to finalize the methodology for field application. The proposed methodology and tools are served as "the World First Methodology and Tools". It is considered as green decommissioning to reduce impact on seabed ecosystem and eliminate pipeline Hg contaminated wastes. Also, it is cost effective and potentially creates a new business opportunity for E&P worldwide.
- Energy > Oil & Gas > Upstream (1.00)
- Government > Regional Government > Asia Government > Thailand Government (0.70)
- Health, Safety, Environment & Sustainability > Environment (0.94)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (0.69)
- Facilities Design, Construction and Operation > Facilities Decommissioning and Site Remediation > Offshore facility decommissioning (0.49)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.47)
Successful Mitigation of Structural Risks for Corroded Conductors in Shallow Water Offshore Wells
Spuskanyuk, O.. (Zakum Development Co.) | Abdulhai, W.. (Zakum Development Co.) | Mahmoud, A.. (Zakum Development Co.) | Mumtaz, S.. (Zakum Development Co.) | Gan, C. Lam (Zakum Development Co.) | Khemakhem, A. S. (Zakum Development Co.)
Abstract Ageing wells in mature shallow water fields may develop corrosion of conductor and surface casings, which reduces their capacity to carry well loads. Novel conductor repair techniques were designed and piloted, a comprehensive well maintenance program was developed to mitigate and minimize the probability of structural failures and to eliminate environmental impact through lifetime of the well. Lessons learned during development and implementation of this program and specific experience from conductor repairs performed using several new techniques are invaluable for companies that experience similar corrosion issues of ageing assets. Qualitative assessment by visual inspection and quantitative detailed ultrasonic testing of several hundred conductors provided an accurate measure of metal thickness of conductor pipes from the splash zone to the wellhead. Physics-based assessment of how the corrosion impacts the well structural integrity was performed in order to establish acceptable, safe limits of corrosion and remaining wall thickness of an integral conductor pipe, which included a simplistic analytical study, detailed structural modeling and 3D finite-element analysis. These analyses allowed the development of safety guidelines and structural failure risk ranking criteria. After initial assessment through analysis of UT scans, all wells in the field have been risk-ranked and prioritized for maintenance and repairs. Cement top-up campaign took place to ensure cement filled the annulus inside conductor to provide additional structural support and stability and to slow down the internal corrosion of the conductor pipe and external corrosion of the surface casing. Blasting and coating of conductor external surfaces in order to stop any additional external corrosion has been performed. Three cost-effective rigless repair techniques to re-establish full structural integrity of the wells have been selected for pilot operations. Welded sleeves were used for several repairs but required extensive engagement of weather-dependent diving services to construct the cofferdam to create dry working area in the splash zone before welding. Two other techniques with the minimum use of diving operations have been used for the first time in the region: external reinforced cementitious grout and combined clamped-welded sleeves. Before execution of repair operations offshore, the full-scale yard testing of clamps was performed to verify capability of equipment to carry the required loads. A number of wells have been repaired using novel techniques with varying duration of operation and several technological and operational challenges related to field execution, quality of design and weather dependence. Without doubt, lessons learned from these trials are essential for future execution of repairs with these techniques. Well management program to ensure structural integrity of offshore wells will extend the life of existing wells, optimize costs by prioritizing operations and re-utilizing same conductor pipes through slot recovery for replacement wells, when necessary.
- Asia > Middle East (0.46)
- North America > United States > Texas > Kleberg County (0.24)
- North America > United States > Texas > Chambers County (0.24)
- Well Drilling > Casing and Cementing > Casing design (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Management (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Abstract A Cathodic Protection system can provide effective corrosion control against external corrosion threats to above-ground storage tanks; be it related to tank construction materials, coating degradation over operational life span or environmental corrosion caused by tank foundation, soil etc. Traditionally, several different types of anode installation schemes were practiced for current distribution to the tank bottom. These were ‘Horizontal or vertical’ anode installation distributed around the tank periphery or angular drilled anode installation to extend the anodes toward center of the tank bottom. Deep-well anode systems with multiple anodes in a single long bore-hole at relatively remote location were also used to provide common cathodic protection system for multiple tanks in tank farm area. These conventional anode-beds were easy to install, monitor and maintained. For safety and environmental reasons in new storage tank construction, an impermeable plastic membrane is now required to be laid under the tank to contain any corrosion leak if it happens. The use of a membrane beneath the tank bottom as secondary containment and as a means of leak detection thwarts any attempt of conventional anode-bed outside the tank periphery to be effective. The anode-bed and references electrodes or other monitoring systems are therefore installed within the space available between the membrane and the tank bottom during construction of the tank, as retro-fitting of anodes during operational service life would not work because of the inaccessibility below the tank bottom. A robust design of the cathodic protection system for a tank bottom is therefore imperative to ensure intended design life. This paper briefly discusses the changing perspectives of the cathodic protection system from conventional anode-beds to a grid system showing the detail design approach adopted and highlights the implications of miss-design based on a practical example of a newly constructed 100 meter dia crude oil storage tank with 40 years design life if relevant design considerations are not addressed.
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- Facilities Design, Construction and Operation > Processing Systems and Design > Tanks and storage systems (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
The Importance of the Stability of Cement Sheaths: Interaction between Cement, Acid, Carbon Steel and Formation and Treatment Fluids
Alsaiari, H. A. (Saudi Aramco) | Sayed, M.. (Aramco Services Company) | Reddy, B. R. (Aramco Services Company) | Metouri, S.. (Aramco Services Company) | Al-Taie, I.. (Saudi Aramco)
Abstract The stability of cement sheaths during well workover, production and intervention is an important element for well integrity and operational safety. Cement sheaths support casing, provide zonal isolation, seal off annuli, and protect casing from corrosive fluids. Understanding the interaction of the cement with the production and intervention fluids under reservoir conditions is essential to prevent unexpected operational problems. This paper provides a systematic study on the interaction between the cement and many oilfield elements including fresh acid, corrosion inhibitor, carbon steel, hydrogen sulfide, and carbon dioxide. A series of laboratory experiments were conducted by exposing set cement to various fluids at temperatures ranging from 50 up to 200 °F. Both fresh and aged cements were evaluated. Cement degradation during production in sour environments could be severe and consequently provide a source of iron- and calcium-related deposits. The severity of the problem depends on the level of degradation and production conditions. The degradation process can also maximize the exposure of casing surfaces to corrosive fluids leading to an increased concentration of dissolved cations in produced fluids, thus, increased potential for inorganic deposits and water-oil emulsion formation. Severe cement degradation can exacerbate the potential of creating easy pathways for toxic gases to the surface. Several advanced analytical techniques including X-Ray Diffraction (XRD) and Inductively Coupled Plasma (ICP) were used to evaluate the condition of the cement before and after the fluid exposure in our experiments. The results indicated that, unlike what has been reported in the literature, acid can significantly degrade a major portion of the exposed Class-G cement within less than two hours if the exposed cement surface area to acid is considered. The exposure to hydrogen sulfide and carbon dioxide did impact the cement degradation, but not significantly. The degradation was found to be a function of acid concentration, fluid additives, and environment conditions. To determine whether cement catalyzes the corrosion process, the average corrosion rates were also calculated. The results were in agreement with field observations and beneficial to optimize the cement stability and to minimize the related operational problems.
- Well Drilling > Casing and Cementing (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- (2 more...)
Step-Change in Maintenance and Inspection to Survive for Mid-to-Small E&P Company in this Continuing Oil Price Down Turn
Panomrit, Agkarat (PTT E&P PLC) | Sri-intra, S.. (PTT E&P PLC) | Limpanachaipornkul, S.. (PTT E&P PLC) | Tanmon, W.. (PTT E&P PLC) | chaisalee, d.. (PTT E&P PLC) | Buato, A.. (PTT E&P PLC) | Sawattanakit, N.. (PTT E&P PLC) | Kanokwareerat, N.. (PTT E&P PLC) | Panmungmee, C.. (PTT E&P PLC) | Udomsri, J.. (PTT E&P PLC) | Chiawwattana, N.. (PTT E&P PLC) | Taranut, N.. (PTT E&P PLC) | Salee, W.. (PTT E&P PLC) | Limsakul, C.. (PTT E&P PLC) | Wichetthammasak, R.. (PTT E&P PLC) | Thamvechvitee, P.. (PTT E&P PLC) | Kanlayanopakorn, N.. (PTT E&P PLC) | Tangpuk, S.. (PTT E&P PLC) | Wipoosanawan, W.. (PTT E&P PLC) | Limprachaya, S.. (PTT E&P PLC) | Nubsuwan, S.. (PTT E&P PLC) | Sitthiwasuwat, T.. (PTT E&P PLC) | Bamrungwong, A.. (PTT E&P PLC) | Pongtemsuk, J.. (PTT E&P PLC) | Chintanapatumporn, S.. (PTT E&P PLC)
Abstract The low-oil price situation impacts many oil and gas producers and operators across the globe. Some oil and gas giants called for cost-cutting or other quick-win means to sharply reduce their cost first with enhancing working performance later. This seems to be the effective, silver bullet solution for big company which wider cost reduction gap can be easily identified, but not for middle-to-small companies of which "Competitive Performance" is a key driver. This paper presents how to survive not only during this difficult time, but also strive for sustainability in the long run. The main emphasis in this paper is paid on "Maintenance and Inspection (M&I)" programs and pertinent activities (e.g. inventory management), which pose the significant share in operating cost in exploration and production business entirely. The reassessment of maintenance and inspection data leads to reconsideration of methods and philosophy to be applied for each installation, system, unit, down to maintainable items. The data structure in enterprise resource planning database is modified to pipe the data systematically to ease this data analysis and support the other continuous improvement when needed. Various techniques have been applied to make our maintenance and inspection more efficient and effective. These rank from simple (e.g. reliability-based techniques, such as Reliability-Centered Maintenance (RCM), Risk-based Inspection (RBI), Safety Integrity Level (SIL) to sophisticated approaches, such as parametric modeling; classical Artificial Neural Network (ANN), Similarity-based Modeling (SBM), etc., which are selected for best-fit with our applications. The obsolescence and aging equipment management is unforgettable – It is built-in with the review process to deliberate how to manage the maintenance and inspection programs to suit with the asset life cycle; in term of total cost of ownership against remaining life and obtainable profits. All stock parameters, associated formula/ calculation in relation with (e.g. reorder points, minimum and maximum quantity limit, etc.) and relevant management codes are reviewed and reinvented to come in close proximity with "Just-In-Time" requirement. Doing so helps reducing the non-movement spare parts in some extent, and in turn, lower the overall inventory cost, for instance, stock holding and carrying cost. Moreover, that optimization are enhanced across the entire organization – Not limited only to one entity. All outcomes from one is fairly shared with others. Then our maintenance and inspection programs become more and more efficient and effective according the number of collaboration rounds and later enable the standardization throughout our company and affiliates. All aforementioned lifts our competitive advantages; obviously the reduction in maintenance cost per Barrel of Oil Equivalence (BOE) approximately 10-30% depending on installation base and makes maintenance job value more meaningful.
New High-Definition Frequency Tool for Tubing and Multiple Casing Corrosion Detection
Martin, Luis Emilio (Halliburton) | Fouda, Ahmed Elsayed (Halliburton) | Amineh, Reza Khalaj (formerly Halliburton) | Capoglu, Ilker (Halliburton) | Donderici, Burkay (Halliburton) | Roy, Sushovon Singha (Halliburton) | Hill, Freeman (Halliburton)
Abstract An electromagnetic corrosion inspection tool was designed to accurately assess corrosion in as many as five nested pipes. This paper provides details of the principles of operations and the methodology of the algorithms used for data processing of this tool. This tool uses the eddy current principle and includes two transmitters and eight receivers. It operates in continuous wave mode at multiple frequencies. Optimized transmitter-receiver spacing configurations and multifrequency operation provide sufficiently diverse information to help assess the metal loss in each individual pipe for a wide range of configurations. The performance of the tool was validated with synthetic and actual data by using controlled tests and experiments. These tests demonstrated the accurate determination of the defect positions and metal loss in each individual pipe of a multiple configuration. To validate the wide operational range of the tool, synthetic tests were used that included challenging scenarios, such as the identification of defects with a total metal thickness of all casings of more than 2 in. or overlapping defects at the same axial position. Finally, the accuracy of the tool in practical scenarios was verified by using results from well tests. The electromagnetic corrosion inspection tool has delivered unprecedented accurate assessments of the fourth and fifth pipes, as well as an accurate assessment of the first, second, and third pipes. The information provided by this tool can significantly improve decision-making for mature well operations, especially in areas with high corrosion rates, and could result in significant cost savings to the operator.
Electromagnetic Corrosion Logs, Insights from Yard Test
Macki, Ali Al (Petroleum Development Oman) | Salmi, Albashir Al (Petroleum Development Oman) | Duggan, Timothy (Petroleum Development Oman) | Delgado, Eduardo (Petroleum Development Oman) | Kechichian, Jackie (Petroleum Development Oman) | Busaidi, Hamood Al (Petroleum Development Oman) | Azri, Nasser Al (Petroleum Development Oman)
Abstract Well integrity is one of the highest operational risks for E&P companies across the industry. As such, well integrity concerns are high priority for operational excellence. Electromagnetic Corrosion Logs have been more frequently acquired as Cased-hole logging services enabling the quantification of multi-barrier well integrity. Due to ease of data acquisition through logging operations and the ability to model remaining metal thickness per-barrier from acquired surveys, demand for Electromagnetic Corrosion Logs has been sharply growing across the industry. Electromagnetic Corrosion Logs can compliment conventional integrity tests and can be used for well integrity compliance where business-critical decisions are accordingly made. Electromagnetic corrosion logs are run more frequently across assets to investigate time-lapse per-barrier integrity status for multi-barrier systems (multiple concentric tubulars). Degradation in barrier integrity in operating wells present integrity risks. Harsh operating environments during production/injection, sour environments, life-time wear and tear, and shallow aquifers all affect wellbore integrity in the form of internal and external metal loss. Electromagnetic Corrosion Logs are currently reported to be capable of quantifying total remaining metal per-casing (separately) up to three barriers. In 2016, a yard test was conducted in Oman to assess the limitations of different Electromagnetic corrosion tools. The test consisted of multi-barrier concentric oil-field tubulars of different sizing and set-up. Four tubular set-ups (simulating routine well completions) were constructed with man-made "corrosion" features to assess raw, processed and interpreted Electromagnetic Corrosion logs. The man-made features included defects of various shapes and configurations distributed axially and longitudinally as well as machined thickness-loss areas with precise thresholds. Multiple service providers with different tools and configurations were requested to acquire corrosion logs through the yard test "completions." This paper investigates Electromagnetic Corrosion Log technology. It illustrates the physics, practice, and applied technology scope of Electromagnetic Corrosion Logs gathered from the yard test and multiple surveys in Petroleum Development of Oman (PDO). The outcome is improved awareness of operational windows, tool resolution and sensitivities, detection capability, data QC and analysis, processing, and modeled thickness outputs. Some discussion is made around the limitation of Electromagnetic Corrosion Logs and the uncertainty in thickness estimation, and recommendations for this technology's scope for application.
- Reservoir Description and Dynamics > Formation Evaluation & Management > Open hole/cased hole log analysis (0.94)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.68)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (0.68)
Abstract Today there are more than 100 Sulphur Recovery Units in the Middle East and many of them have been in operation for 10 years or longer. Corrosion can be one of the most challenging issues in these units due to the presence of hydrogen sulfide, sulphur dioxide, elemental sulphur and water. If operated within the normal operating temperature range, corrosive conditions should not occur; however, if upset conditions result in temperatures which are too high or too low, several corrosion mechanisms are possible. This issue has resulted in many instances in which existing units have been forced into emergency shutdown for several days to perform maintenance. This results in production loss and the potential for significant environmental impact due to flaring acid gases. API 571 documents most of the major corrosion mechanisms in the Claus process such as sulfidation, oxidation, flue gas dewpoint corrosion and wet sulphur corrosion. However, it does not address specific means of controlling corrosion, taking into account different technologies available for tail gas treatment. This paper demonstrates the fundamental corrosion issues encountered in SRUs and proposes protective actions. Guidance related to start-up, shutdown and normal operation is also provided for establishing appropriate operating limits to achieve safe and reliable operation for corrosion avoidance. This paper takes a unique approach which considers both theoretical and practical, real-world experience in the mitigation and monitoring of corrosion control. Operators are provided with tangible recommendations that can be applied to their facilities. Protection against atmospheric corrosion is not in the scope of this paper. This paper has been prepared based on a review of several industry publications, which address specific corrosion mechanisms in SRUs. The main objective of this paper is to provide a high-level overview of these works, while also offering guidance on the safe operating envelope of the facility, to avoid excessive corrosion. Most of the metallurgy in an SRU is typically specified as carbon steel, which is adequate when the unit is operated within safe operating limits. However, if operated outside the acceptable range (above or below), corrosion can be swift and severe, as will be described.
- Asia > Middle East (0.48)
- Europe (0.34)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- (2 more...)