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ABSTRACT Microbes can flourish in a wide range of environments and are also present in oil reservoirs, wells and topside facilities. They may constitute a massive threat to the well and facility integrity. For instance, bacteria and archaea may live in biofilms bound to metallic surfaces of the field's infrastructure. By extracting nutrients from fluids, they trigger cathodic reactions, which leaches iron-ions from steel and cause a severe corrosion (Microbial Induced Corrosion: MIC). At the same time the corrosion products, the metabolic products and the biofilm build-ups may cause clogging of reservoirs, pipelines and filters, called โbio-foulingโ. In numerous cases the changes in microbial populations are the cause of increase of corrosive and hazardous contaminants in the production fluids such as H2S and CO2 (souring). New advances in Molecular Microbiological Methods (MMM) using DNA technologies allow us to identify all species present in a sample. This is achieved by the Next Generation Sequencing (NGS) technologies. The advent of NGS and other MMMs has led to new insights, and the focus is now more towards identifying all microbial species, rather than quantifying specific groups, which was more common in the past. NGS has become a quick turn-around time and cost efficient technology, which allow microbial monitoring of reservoir and injection fluids in the oil and gas production process. The analysis of mineral and biological scale from wells and pipelines, filter residuals and drill cuttings in combination with isotope analysis and QEMSCAN mineralogy analysis facilitate the determination of the origin, location and severity of microbial contamination. The changes of the microbial populations are often an indication for the deterioration of the "field health", which could occur in the reservoir, in the well bore or at the top-side facilities. The workflow presented here is therefore called a โhealth checkโ and consists of establishing a โbaselineโ and โmicrobial mapโ. Subsequently, a tailored monitoring analysis program can be defined in order to evaluate the success of mitigation activities. Based on the results of the monitoring analyses the mitigation and inhibition can be optimized, which lead to a better field health and facility integrity and significantly reduces repair costs and downtime.
- Geology > Mineral (0.93)
- Geology > Geological Subdiscipline > Mineralogy (0.34)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Microbial methods (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology (1.00)
- (2 more...)
Abstract The effectiveness of poly (2-acrylamido-2-methylpropane sulfonic acid) (PAMPS) and copolymers with acrylic acid (AA) and acrylamide (AM) magnetic nanogels as protective corrosion of CS in reaction with water by (EIS), (EFM) and tafel polarization method. Polarization method demonstrated that all the polymers are mixed inhibitor type. (EIS) Electrochemical impedance given that the attendance of these investigated polymers declines the double layer capacitance and improvement the charge transfer resistance. The polymers adsorption on surface of steel was follow isotherm Temkin. The morphology of the CS surface was examining by (EDX) energy dispersive X-ray and (SEM) scanning electron microscope. The data obtain showed improvement in efficiencies for inhibition with raising the dose of inhibitor. Introduction CS is the common regularly utilized pipeline materials as a part of petroleum creation. In any case, it is exceptionally inclined to corrosion in environments include sulphur [1]. Corrosion of sulfur has been one of the corrosion sorts in gas/oil manufacture, offering ascend to the pipelines failure and equipment's and utilized in biggest economic reduction and accidents. Likewise, spillage of raw petroleum because of endures consumption of pipelines would actuate fire accident, and natural contamination [2-4]. Explored to comprehend its mechanism, decrease the corrosion rate, additionally create experimental models to survey and foresee the parametric effects and the states-of the-art of internal corrosion of pipelines [5-12]. Theoretical approaches provide means of experimental of these reactions and there are many reports connection with this area [13]. Last papers have study the connection between the efficiency and structure of the inhibitor molecule, but low attention has been paid to the reliance of the protection efficiency on the size and electronic distribution of the protective molecule, Relation between chemical structure and inhibition efficiency was not research, The super paramagnetic Fe3O4 nanoparticles covered with polymers are usually connected to the magnetic cores to ensure a strong magnetic [14]. Attractive nanogels of regular interest are ferromagnetic magnetite (Fe3O4) covered with cross-connected polymer nanogels. The Fe3O4 center has solid attractive characteristic and super paramagnetic conduct, is of generally declines danger to the human body when epitomized in the defensive shell of polymer, which is cross-connected hydrogels polymer. The shell keeps the Fe3O4 center from total oxidation. In this appreciation, the utilizing of nanogels particles as a part of the field of consumption hindrance insurance for steel rather than ordinary natural inhibitors can deliver uniform flimsy film (with no pine opening because of cross-connected polymers) on the surface of CS to coat all surface with no deformities which give focal points over typical natural inhibitors. A few strategies have been produced to get ready attractive miniaturized scale and nanogels, for example, reverse microemulsion polymerization and emulsion polymerization [15-18]. The target of this paper is to calculation the inhibitive effect of these polymers on carbon steel in formation water by various electrochemical methods.
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.34)
- Reservoir Description and Dynamics > Formation Evaluation & Management (0.74)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.69)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (0.69)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (0.48)
ABSTRACT In a time when drilling efficiencies are significant, the advancement of conventional clear brine systems has led to both economic and technological breakthroughs. Clear brine fluids have been in the industry since the 1950's, and since inception, different base brines have been utilized to maintain different densities. Calcium chloride is a great base fluid due to its natural density and highly lubricious nature. By adding calcium nitrate, densities have been increased to 1.6 sg (13.35 lb/gal), exceeding the density of potassium formate 1.57 sg (13.1 lb/gal). These calcium brine systems can be cost effective providing a reduction in cost for base fluid up to 90% as compared to formate or bromide systems. However, divalent brines are known for having excessively high corrosion rates and compatibility issues when used with polymers. By focusing efforts on process control and product compatibility, low corrosion rates can be achieved in a brine system. After exhaustive autoclave testing, a corrosion package was developed and perfected in the field. Results of a 140-well dataset showed the calcium chloride system with a novel corrosion package yielded better results than formate brines employed in the same area. The exhaustive efforts in the field also led to determining a suitable flocculent polymer that can hydrate in the calcium chloride/calcium nitrate dual-brine system. This novel application of a polymer provided improvements in both corrosion and drilling performance. This paper discusses the use of clear calcium chloride brine drilling fluids in drilling over 140 wells and the challenges overcome. It also details the equipment used and highlights the comprehensive technique for evaluating all aspects of the drilling fluid. INTRODUCTION Clear brine fluids create density without the need to maintain viscosity solely to carry weight-material particulates as all the weight-material is totally dissolved. The fluid density is dictated by the amount and type of salt used. Each salt has a maximum concentration before it reaches saturation limiting the maximum density of the solution. Thermal expansion of water affects the solubility, crystallization point, and density of clear brine.
- Materials > Chemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Lifecycle > Treatment (0.49)
- North America > United States > South Dakota > Williston Basin (0.99)
- North America > United States > North Dakota > Williston Basin (0.99)
- North America > United States > Montana > Williston Basin (0.99)
- Well Drilling > Drilling Fluids and Materials > Drilling fluid selection and formulation (chemistry, properties) (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
ABSTRACT Nowadays most of the Oil and Gas Companies, in view of a project for the exploitation of a new shallow water oilfield, are considering to reuse existing offshore structures removed from previous service site. This solution is considered strategic, in comparison to the construction of a new platform, with respect to the time required to production, which can be anticipated. Moreover the cost benefits may prove significant taking into account the lower price of the used platform compared to the cost to be incurred for the design/construction of a new structure. Cost saving is the issue but, of course, also the structural safety is to be considered as primary target: therefore, in view of the possible purchase of the existing structure, it must be carried out an appropriate assessment in order to confirm the engineering feasibility of the project and analyze the costs with the purpose to quantify the economic benefits. First, the feasibility study consists of evaluating, by means of a system structural analysis, the residual life of the platform in relation to the new installation site conditions (e.g. soil, waves, current, etc.), then the platform assessment shall include the execution of a gap analysis between the requirements of codes & standards, specifications, procedures used as reference for the original project and those defined by the potential purchaser in order to highlight any discrepancies. As a definitive step, a survey must be carried out according to the "condition assessment plan" prepared on the basis of the findings of the above mentioned activities. This plan is intended to describe the inspection activities by defining, for example, the non-destructive methods and extension, the laboratory mechanical and chemical tests to be carried out. In addition the "corrosion assessment" of the existing structure must be carried out during the survey. Based on the findings coming from the survey, additional checks and tests will be carried out; moreover, if necessary, a refurbishment, repair or modification plan is to be issued. In conclusion, the correct execution of the above described activities will provide to the potential purchaser greater confidence on the usability of the existing platform and all the elements needed to perform an accurate economic evaluation for his final decision making.
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
- Facilities Design, Construction and Operation > Offshore Facilities and Subsea Systems (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (0.70)
ABSTRACT The Oil and Gas industry is currently facing the problem of the increasing number of pipelines at the end of life. The pipelines re-qualification is an important aspect of the integrity management process aimed at pipeline life extension under safety conditions. The main failure mode for ageing pipelines is due to corrosion. In this paper, a complete methodology for the re-qualification of a pipeline case study is described. The selected approach integrates the Reliability Analysis of the corroded pipeline with the Quantitative Risk Analysis in order to evaluate the present and future level of risk. For the Reliability Analysis a software tool for the calculation of the failure probability over time was developed. The data collected during the inspections performed along the pipeline were used for the integrity assessment. The uncertainties associated with the inspection tool, corrosion growth rate, pipeline geometry, material strength and operating pressure have been modeled through Monte Carlo simulations and used to determine the pipeline failure probability. A complete analysis of the consequences of the possible incidental scenarios has been performed using a quantitative approach. The software tool for the failure probability calculation was integrated with the software tool for risk recomposition in order to evaluate the specific risk level of the corroded pipeline and the evolution over time. The calculated Local Specific Individual Risk (LSIR) curve was compared with the selected safety targets in order to define the possible life extension period of the pipeline and to plan future inspections. The presented methodology permits a detailed analysis of the pipeline integrity and supports the integrity management process with the aim of maximization of the operative life of the pipeline together with the minimization of the cost of repair while maintaining the minimum safety goals projected for the pipeline.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Management > Risk Management and Decision-Making > Risk, uncertainty, and risk assessment (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Offshore pipelines (1.00)
- (3 more...)
ABSTRACT Asset Integrity Management (AIM) for Pipelines is a very critical task in the Oil & Gas energy industry. Pipeline failures may lead to severe environmental damages as well as huge losses (in terms of life, property, production, commodity and reputation). Operators shall effectively evaluate and mitigate associated risks to a level that is compliant with their own policy, standards and regulations. This work aims at describing a methodology for cost-effective decision making during the pipeline network risk management process applicable to any pipeline system. The methodology is identified as "Pipeline Integrity and Risk Management Decision Making Strategy" (PIRM-DMS) and helps owners understanding how (and where) to prioritize the allocation of resources for pipeline risk and integrity management. Since all the decisions have to be based on a correct cost-benefit evaluation, one of the most important steps of decision-making is always the risk assessment process, for this reason the multi-level risk assessment methodology applied in PIRM-DMS will be presented in detail. This methodology is supported by different risk assessment models, which change with the level of accuracy required and the type of asset. The risk assessment models carry experts' knowledge, which has been included performing a risk indexes pairwise comparison through the Analytic-Hierarchy-Process (AHP). The risk assessment models take also into account data reliability by means of managing the weight of each risk contribution index depending on data availability. Since risk is mainly managed performing IMR (Inspection-Maintenance-Repair), one goal of this work is to provide guidelines to support operators in IMR technology selection. Thus two IMR support decision models have been developed (one for inspection and one for intervention). Another aspect that is crucial for pipelines risk management is the integrity evaluation. This work provides a practical example of integrity analysis by comparing results of two periodic ILI campaigns with intelligent pigs. In order to effectively compare the data, an alignment algorithm has been defined, for a successful comparison of each defect evolution with time. This work results from the collaboration between Cranfield University and D'Appolonia. This cooperation has facilitated the merger between a methodologic approach with an industrial solution, which has been tested through a real case study. The test has revealed that the PIRM-DMS is extremely useful because it can be applied to assets with different features and dimensions, moreover, it is developed on multiple echelons, reducing or increasing the level of detail depending on the operator needs.
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Management > Risk Management and Decision-Making > Risk, uncertainty, and risk assessment (1.00)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
Abstract The most severe corrosion due to bacterial activity in pipe steel for the transportation of water and the injection systems is influenced by sulphate reducing bacteria (SRB), thiosulphate reducing bacteria (TRB) and others microorganisms. In the aim to reduce the impact of bacterial corrosion, steel pipes were substituted by fiberglass pipes. These types of materials are very resistant to corrosion and the life of use was prolonged. These bacteria can be halophiles or thermophiles which can explain their strong tolerance to chlorides and to high temperatures. Fiberglass pipes are used for the water transportation that be used for the water flooding systems in the oil fields and fire systems. During the opening of a section of the fiberglass line, the scale found inside this line, produced a smoke that was followed by a fire that provoked the inflammation of the fiberglass. Also, the aim to understand the phenomena and after the suspicion of the role of some bacteria in this phenomenon, we carried up in laboratory for the microbial characterization of fiberglass coupons mounted in corrosion loop. The microbial analysis of these deposits and biofilms revealed the presence of a heterogeneous population of facultative aerobic bacteria and anaerobic bacteria. The identified bacteria in all the samples show the presence of sulfate-reducing bacteria, methanogenic bacteria and fermentative bacteria. We think that by synergic effect, the growth of these microorganisms transform heavy organic molecule to methane and others chemicals species. The methane is gas and under the effect of the sun may start fire.
- Materials (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Water & Waste Management > Water Management > Constituents > Bacteria (0.91)
- 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)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
ABSTRACT: Internal CO2 corrosion is a dangerous phenomenon which affects hydrocarbon transportation in pipelines, with occurrence of production spill and safety issues. Models are available to determine the exp ected corrosion rate and to allow selecting suitable materials to minimize failures. However, different conditions can be experienced during the life of a pipeline and there is a need to predict the occurrence of damage for a be tter risk management. This paper presents comparison of predict ive models results with field damage observations, with the final objective of obtaining data for the assessment of pipeline life. Corrosion models were thus coupled with hydraulic analysis performed with the help of flow dynamics codes. Obtained results show that flow dynamics can help in assessing risk levels, which can be dif ferent in different region of a long p ipeline. Flow regimes and the potential water wetting at the pipeline wall are e stimated using one-dimensional code and simple models available in literature. Computational Fluid Dyna mics (CFD) is also evaluated as a powerful tool in some critical sections. The proposed methodology can be considered as an integrated approach for CO2 corrosion risk prediction for differ ent pipeline sections. As it is observed in field experience, damage can be high in some section of a pipe line, while in near sections no corrosion is active. The predicted corrosion rate is actu ally a function of local flow conditions and the comparison with observed damage is expected to help in the planning of inspection and maintenance activities. This methodology is just a first attempt to couple corrosion and fluid dynamics analysis and further applications are foreseen to allow completing the procedure and proposing a methodology for risk assessment of pipelines transporting hydrocarbons
- Research Report > New Finding (0.34)
- Research Report > Experimental Study (0.34)
ABSTRACT: In oil and gas production, carbon steel is widely used as the material of construction for downhole tubing, vessels and piping. Although it is inexpensive compared to stainless steel, carbon steel is susceptible to corrosion attack from CO2 and/or H2S present in the produced water. Therefore, the corrosion risks of this material have to be proactively managed. To this end we have to develop and to implement corrosion control strategies which integrate risk assessment and corrosion control with corrosion monitoring and inspection. The application of corrosion monitoring as part of a corrosion control strategy is complex and often becomes the responsibility of engineers who are not experts in the field. The aim of corrosion monitoring is primarily to ensure that the design life is not being adversely affected or compromised and also to maximise the safe and economic operational life of a facility. When undertaking corrosion monitoring it is important not to rely on just one method. The best results are obtained by using a range of techniques. Some corrosion measurement techniques can be used on-line, constantly exposed to the process stream, while others provide off-line measurement, such as that determined in a laboratory analysis. Some techniques give a direct measure of metal loss or corrosion rate, while others are used to infer that a corrosive environment may exist. The aim of this work is to provide an aid to the operator in the choice of the corrosion monitoring technique
- 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)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)
ABSTRACT: Atmospheric plasma spray is a very efficient thermal spray technique to obtain coatings resistant to corrosion and wear. Coatings obtained by thermal spray techniques are used in many applications where wear and abrasion resistance are required and due to the simplicity of application and facility of the covering of large areas, protection against corrosion is made possible The corrosion behavior of stainless steel coating samples was investigated in two medium: seawater and oilfield production water using the scanning electron microscope (SEM) and electrochemical techniques (potentiodynamic polarization and AC Impedance Spectroscopy). The surface morphology and microstructure of the specimens, before and after the corrosion experiments, were investigated by SEM analysis. The test, which were performed with Potentiodynamic polarization shows that the stainless steel coating ennobles the metal by anodic protection effect. The test, which has been performed with Electrochemical Impedance Spectroscopy, indicates the barrier properties of coating. Stainless steel coating was more effective in oilfield production water compared to seawater. This is probably due to the presence of oxygen in seawater, normally absent in producing oilfield systems. Thus, the aim of this work was to study the plasma sprayed stainless steel coating onto a steel substrate in terms of the corrosion protection of the facilities in gas and oil field mainly, flow lines (oil, water, gas) and Storage Vessels with Separated Water Bottom. Key words: Petroleum industry, corrosion, protection, stainless steel coatin
- 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)
- Facilities Design, Construction and Operation > Pipelines, Flowlines and Risers > Materials and corrosion (1.00)