bluuebunny/crossref_metadata_2025_split huggingface dataset:
A New, Low Corrosive Fluid to Stimulate Deep Wells Completed With Cr-based Alloys
Authors: Wolf C. A. , Nasr-El-Din H. A. , Bouwman A. , Bang E. R. , Naylor E. 
Published: May 2012

Abstract
Acid treatments of deep wells completed with Cr-based tubulars represent a real challenge to the oil industry. On one hand, Cr-based tubulars are used to protect against CO2 corrosion, but on the other hand, the protective layer (Cr2O3) dissolves in hydrochloric acid (HCl)- a common stimulation fluid. This fact makes protection of Cr tubulars during acidizing very challenging, especially at high temperatures. At temperatures above 200°F, there is a need to add an intensifier. Most of them depend on heavy elements (Cu, Sb), or are not effective above 300°F (e.g., KI).
Over the last decade, we developed a new chelate, glutamic acid N, N-diacetic acid (GLDA) that can dissolve carbonate minerals from carbonate and sandstone formations. This chelate can form worm holes in carbonates (both calcite and dolomite) and does not destabilize clay particles. In the present paper, the corrosion rate of GLDA is compared with other chelates and simple organic acids that are used for carbonate dissolution, such as hydroxyethylethylenediaminetriacetic acid (HEDTA), acetic and formic acid. All corrosion tests were conducted at high temperatures and pressures and extended for up to 6 hour at temperature and pressure. The coupons were examined thoroughly after the tests, and the spent fluid was analyzed for key ions (Cr, Ni, Mo, Fe, and Mn).
The results show that GLDA at 20 wt% gives almost no corrosion with Cr-13 up to 300°F. Unlike GLDA, HEDTA was found to be corrosive at pH=3.8 and requires attention when used in wells completed with Cr-13 based tubulars. On more corrosion resistant Cr-based metals, like super Cr-13 and Duplex the corrosion rate of GLDA is still far below the acceptable limit of 0.02 to 0.05 lbs/ft2 up to 350°F. In wells with corrosive sweet and sour gases tubular consisting of low carbon steel, Cr-based steel or corrosion resistant Cr-Ni alloys can be effectively protected by a combination of GLDA with a minimal amount of corrosion inhibitor. Due to its favorable environmental profile this mixture meets all the OSPAR requirements for use in the North Sea. Based on our results, GLDA solutions can be used to stimulate carbonate and sandstone wells completed with Cr-based tubulars, while maintaining the integrity of the tubulars.
Acoustic Monitor Threshold Limits for Sand Detection in Multiphase Flow Production System
Authors: Odigie M. E. , McLaury B. S. , Shirazi S. A. , Cremaschi S. 
Published: May 2012

Abstract
Solid particle erosion in the oil and natural gas industry can be detrimental to piping and plant equipment, which can lead to production shutdown and other economic losses. Therefore, it is important to be able to detect and quantify the amount of solids present in the piping and plant equipment. This paper presents experimental results obtained using acoustic sand detectors for a broad range of operating conditions at the Tulsa University Sand Management Projects (TUSMP). The effectiveness of sand monitoring in multiphase flow conditions is evaluated and presented. Experimental impingement measurements were performed with acoustic monitors while varying superficial gas and liquid velocities, sand size, and pipe flow orientation. The major focus was to determine the threshold limits for the acoustic sand monitor. Different tests with various velocity combinations to achieve annular, bubble, dispersed-bubble, mist, slug and stratified flow regimes were performed using pipe sizes of 2-inch and 4-inch diameters, and 20 µm, 150 µm and 300 µm sand sizes. The effects of sand size and flow regime on threshold sand rates as sand injection rates change were investigated. The threshold sand rate results for these multiphase flow regimes were determined experimentally and statistical analysis were performed to eliminate the effect of background noise generated when no sand is present in the system. Threshold limits observed for the stratified flow regime was similar and sometimes higher than the ones for annular and slug flows with the slug flow threshold limits being the lowest of all three regimes. Data for other flow regimes like liquid only, bubble and dispersed bubble flows were compared to annular, slug and stratified flow; the highest threshold limit was recorded for liquid only flows closely followed by the limits for bubble flow compared to the other flow types, the smallest threshold limit was recorded for dispersed bubble flow in the horizontal pipe orientation for the flow conditions tested.The threshold sand detection limits for 150 µm and 300 µm sand types are presented and discussed.
Multi-Faceted Approach for Optimizing a Microbial Control Program
Authors: Keasler Victor , Bennett Brian , Keller Carrie , Kuijvenhoven Cor , Mahon Tom , James Stewart 
Published: May 2012

Abstract
Microorganisms are a major challenge for the petroleum industry and can lead to microbiologically influenced corrosion (MIC), reservoir souring, or biofouling. Typically used standard methods for microbial identification (i.e. MPN) have limited success at identifying problematic organisms and providing timely feedback. Consequently, it is important to develop a multi-faceted approach that provides faster and more insightful results on the risk of microbial difficulties.
A three-part approach was developed and implemented at Shell's Ursa platform to understand whether recent failures on the production system were the result of MIC and the efficiency of the biocontrol strategy on the recently installed waterflood to prevent system failure and reservoir souring. The approach involved 2nd generation ATP quantification for rapid enumeration of actively-growing microorganisms, as well as microbial enumeration and speciation using molecular methods.
Recent failures on the production system were believed to be the result of under-deposit corrosion and microbial attack. However, culture-based methods revealed low numbers of problematic microbes, suggesting that the failures were not from MIC. Using ATP quantification, the presence of active microbes was observed at the manifolds and shown to increase throughout the production system. Speciation and enumeration results confirmed that problematic microorganisms were present and this additional information allowed for identification of optimized treatment locations in the production system to minimize the risk of MIC.
For the waterflood, the new microbial analysis approach confirmed that the biocide program is successfully minimizing the risk of fouling, equipment failure and reservoir souring. ATP testing revealed occasional locations of elevated microbial growth and their potential for downstream contamination, allowing for further optimization, but overall demonstrated the biocide regime to be effective. The success of the biocide regime was determined by a reduction in active microorganisms and a population shift to Bacteria that are not likely to contribute to reservoir souring.
This audit revealed a clear understanding of the microbial risks at Ursa, including areas that were performing well and those that needed required changes. This process is an excellent tool for microbial risk identification and biocide program optimization.
Development of Double Layer Metal Thermal Spray: Novel External Corrosion Mitigation Method for Gas Well Tubing
Authors: Li Qiongwei , Yang Quan'an , Dong Xiaohuan , Li Mingxing , Xi Yuntao 
Published: May 2012

Abstract
This paper discussed the corrosion characters and new double layers metal thermal spary technology for gas well tubing in Erdos basin, Changqing field. Some gas wells produce formation brine, also contain low H2S content and medium CO2 content. (water/gas ratio lager than 0.2m3/104m3, and averge total ions strength is 120g/L, Cl− nearly 80g/L). The electric-chemical corrosion causes the workover lifetime of gas well less than 5 years.
On the external surface of SSC-resistant carbon steel (80S) tubing, the double metals protection layers of 13Cr and Aluminum were designed and applied by high speed arc spary technology. Physical and corrosive properties were researched at simulation and HT/HP conditions.
More than 15 wells were applied by this method in recently 4 years. Before workovering, the lifetime of those wells were not more than 5 years, also lower than regulation workover time of 8 years. At 4 years ago, the corrosion situations of 3 wells which would be workovered were inspected using the multifinger imaging tool and magnetic thickness tool, MID-K logging equipments. By now, those wells were logged (MIT+MTT) again and showing a good condition.
Pitting Behaviour of Lean Duplex Stainless Steels in Marine and Oilfield Environments
Authors: Aribo Sunday , Neville Anne , Hu Xinming 
Published: May 2012

Abstract
Lean Duplex stainless steels are becoming attractive for applications in oilfield and marine environments due to their economic advantages, very good mechanical properties and relatively good corrosion resistance. However, there is little information about the pitting behaviour of lean Duplex stainless steels in oilfield and marine environments. This paper discusses the tendency for pitting corrosion to initiate through an evaluation of breakdown potentials of lean Duplex stainless steels UNS S32101, UNS S32304, LDX2404, standard Duplex stainless steel UNS S32205 and Austenitic stainless steels, 304L and 316L in aerated 3.5% NaCl and a CO2-saturated oilfield brine solution. Electrochemical measurements were made using a three-electrode electrochemical set up using an Ag/AgCl reference electrode and a platinum counter electrode. The results showed that breakdown potentials are generally higher in aerated 3.5% NaCl than the CO2-saturated oilfield brine solution for all the alloys tested. Lean Duplex stainless steel UNS S32101 and Austenitic stainless steel 304L showed comparable breakdown potentials in both environments while lean Duplex stainless steel UNS S32304 and Austenitic stainless steel 316L also have comparable breakdown potentials. There does not seem to be a universal relationship between Pitting Resistant Equivalent number and breakdown potential for the lean Duplex and Austenitic stainless steels.
Performance of Synthesized Amine-based Corrosion Inhibitors in Concentrated HCl Acid Solutions: Effect of Intensifier
Authors: Al-Taq A. A. , Ali S. A. , Haji H. H. , Saleem J. A. , Al-Ibrahim H. A. 
Published: May 2012

Abstract
Mono and diamine compounds were synthesized from 1, 12-dodecanediamaine, and evaluated as acid corrosion inhibitors for coiled tubing steel. The inhibition behavior of these compounds in concentrated HCl acid was examined using a gravimetric method. Weight loss tests were conducted in 28 wt% HCl acid at 60, 70 and 80°C for 2 hours. The results showed that both mono and diamine inhibitors exhibited a good protection efficiency for coiled tubing steel in 28 wt% HCl acid. However, monoamine compounds showed better performance. Addition of an intensifier was effective to enhance protection efficiency for both amine moiety compounds where more than 99% protection was obtained for some inhibitors. The effect of intensifier concentration on inhibition efficiency is also addressed in this paper. The results obtained are very promising and suggest that some of examined corrosion inhibitors have a good potential to be used in acid stimulation treatments of oil/gas wells.
Superior High-Strength Drill Pipe Adopted in Harsh Environment
Authors: Inoue Tomoya , Kyo Masanori , Miyazaki Tsuyoshi , Sakura Koji , Fukui Toshikiko 
Published: May 2012

Abstract
S150 drill pipe was developed during construction of the scientific drilling vessel Chikyu, and has been used in the past scientific drillings. On the other hand, during past drillings, Chikyu faced harsh environments such as a high-current or a corrosive environment in addition to deep drilling. To reach deep drilling in such a harsh environment, a higher strength and reliability drill pipe, as well as strength evaluation using the high-strength drill pipe, is necessary.
Superior high-strength drill pipes, S155 and S160, possessing high reliability, such as corrosion resistance, have been developed. Pitting corrosion resistance, which causes stress concentration, is required to prevent fatigue failure. Also, consideration on possibility of SSC under low temperature at seabed is required because it would be a cause of fatigue.
Regarding deep drilling and extended reach drilling, required feature is fatigue resistance of not only pipe body but also tool joints. In particular, the tool joint starts to become the cause of wearing out, mud pressure loss, mud bedding, heat cracking, and failure itself.
The concept of the high-strength drill pipe, which we have developed, achieves high toughness and reduction of stress concentration along full string in the salt water to eliminate elements of fatigue phenomenon. The development includes the pipe manufacture process such as welding line performance, heat treatment methodology, the experimental investigation such as fatigue tests under salt water with or without pitting, and analytical investigation.
The superior high-strength drill pipes described in the paper possess not only the high-strength performance but also high fatigue resistance in the corrosive environment. These can exercise the potential capability in the deep drillings, extended reach drillings, and harsh environment drillings.
Investigation Self Healing Property of Cerium Nitrate in Organosilane Pretreated Anti Corrosion Coatings
Authors: Zaferani Sadeq Hooshmand , Peikari Mahmood , Zaarei Davood , Danaei Iman , Fakhraei Mohammad javad 
Published: May 2012

Abstract
The barrier property and self healing behavior of the coating systems containg organosilane and epoxy was investigated. The organosiolane componenet of coatings was doped with cerium nitrate and applied on cold rolled carbon steel substrates. Electrochemical impedance spectroscopy (EIS) and immersion tests were used for assessment of corrosion resistrance behaviour of coatings. Also SEM and EDS techniques were employed to investigate the self healing ability of cerium nitrate. Addition of 2 wt. % of cerium nitrate into the coating solution led to superiour self-healing property for scribed coating systems. Furthermore healing mechanism of cerium nitrate pigments was explained in detail.
MIC Risk Assessment of the Halfdan Oil Export Spool
Authors: Skovhus Torben Lund , Holmkvist Lars , Andersen Kenneth , Pedersen Heidi , Larsen Jan 
Published: May 2012

Abstract
Monitoring of Microbiologically Influenced Corrosion (MIC) in the oil industry has in the past been conducted mainly on sulfate-reducing bacteria (SRB) using cultivation based techniques. However, with the introduction of novel DNA-based methods for enumeration of microbes, more accurate and fast methods are now available which offer better determination of MIC on a routine basis.
The content of produced water in the Halfdan oil system during production is relatively low (BS&W &lt; 1–2%) and MIC has for this reason not been considered to be a threat to the system integrity. Initial results from wall thickness inspection of oil export spools have indicated on-going corrosion. As a consequence, spools have been replaced, enabling sampling of cut-out sections of the spools. These cut-out sections have been sent onshore to DTI Oil & Gas for further investigation of general corrosion, MIC and scale composition.
The investigation demonstrated that the analysed Halfdan oil export spool sections were highly corroded. This conclusion was based on visual inspection of the metal surfaces of the cut-out sections that revealed presence of under-deposit and pitting corrosion underneath thick layers of solid scale material. In support of the visual indications of corrosion, it was demonstrated that MIC related microorganisms were present in the solids in close contact with the metal surface together with corrosion products. In particular, high numbers of the hydrogen consuming methanogens (108–109 cells g−1) were situated in the scale directly in contact with the carbon steel pipe wall. These important findings could only be achieved when results obtained from X-Ray analysis (WDXRF) and visual inspections of the oil export spools were combined with DNA-based enumeration methods (qPCR).
Based on the obtained results, this paper discusses how microbial numbers obtained from DNA-based enumeration methods are evaluated and interpreted in the best way with respect to general risk assessment and system integrity measures of aging offshore assets in the Danish Sector of the North Sea.
Injection Seawater versus Produced Water SRB and Archaea Populations in Oilfield Systems
Authors: Hoffmann Heike , Spark Iain 
Published: May 2012

Abstract
Seawater Injection is an essential procedure in many offshore facilities in the North Sea. This water passes through a variety of different treatments and environments. It is chlorinated, filtered, deoxygenated and treated with biocide and other chemicals. The water is then injected into reservoirs under high pressure and sometimes high temperatures, to eventually (after months or years) break through into the production system, where it is subject to various different temperature environments.
Microorganisms react rapidly to changes in their environment, particularly temperature and salinity; given their short generation times, the effects on the microbial population can be pronounced. The objective of this study was to characterise the microbial communities entering and leaving the reservoir with particular emphasis on sulfate-reducing bacteria (SRB) and Archaea, which are believed to be the major cause of microbiologically-influenced corrosion (MIC).
Denaturing gradient gel electrophoresis (DGGE) and fluorescence in situ hybridisation (FISH) were applied to sessile and planktonic samples collected from a number of North Sea seawater injection and production systems to compile a database of the microbial communities found in these systems. The FISH data were compared, to determine common traits and gross differences between topside seawater and production equipment locations. Additionally, the counts of SRB/ Archaea types were assessed and consideration was given to how these may influence the risk of MIC. DGGE data was used to track certain organisms through the systems to find commonalities; primarily, if there were any relationship exists between biofilm communities at different locations in the two systems.
The results indicate that there are similarities as well as subtle differences between the two systems and these are discussed in detail in this paper.
Micelle Detection for Optimising Corrosion Inhibitor Dose on an Offshore Platform
Authors: Mackenzie Cameron , Perfect Emma 
Published: May 2012

Abstract
This paper builds on the evidence for the optimum dose of organic film-forming corrosion inhibitor (FCCI) being at the critical micelle concentration (CMC) of the surfactant components, and the concept of micelle detection as a tool for understanding the effectiveness of the inhibitor dose in the field, which has been presented previously. It extends the underlying principles from laboratory testing, to the rapid analysis of field fluids and explores the different results available from alternative instrumentation.
An inhibitor optimisation trial was undertaken on an offshore oil production platform for protection of a subsea pipeline used to tie back wells 10 miles from the platform. Two micelle detection devices were used, both primarily using fluorescence detection – a simple handheld device for offshore testing and a more complex device used for testing shipped samples in an onshore lab. Electrochemical corrosion monitoring was also used to analyse the produced fluids as the inhibitor dose was varied from zero to 200% of the estimated optimum dose.
Results were clouded by a number of operational issues outside the control of the experiment but interpretation of the whole suggested that the offshore portable micelle analysis was overcome by large quantities of dispersed oil which masked the optical process. However the onshore testing gave some promising results, demonstrating a correlation between increased micelle levels and high inhibitor dose and suggesting that the original dose was sub-optimal.
These experiments supported the need to use the more complex instrument to be able to detect micelles in very impure systems. Making and testing such a device suitable for field operations is now a priority.
Challenges of Integrity Management of Pipelines and Erosion Control in Sand Producing Wells
Authors: Shirazi S. A. , McLaury B. S. , Husen A. A. , Venkatesan K. , Nadeem A. , Hassaballa S. A. 
Published: May 2012

Abstract
Sand production in oil and gas wells is becoming an increasing problem for operators due to sand settling, under-deposit corrosion, and/or erosion especially in sub-sea environment. The paper describes application of ultrasonic (UT) pipe wall thickness measurements and erosion calculations in assessing integrity management of pipelines in a subsea gas producing field. The subsea gas wells were completed with downhole sand control because of the unconsolidated nature of the reservoir sands. The gravel pack completions were designed to stop sand but allow some fines production to prevent plugging of the gravel packs and screens and hence loss of productivity. Some solids production was therefore expected over the life of the fields. After some time when additional gas wells were brought online, higher than expected sand production was observed. Thus, operators commissioned sand erosion studies and conducted UT wall thickness measurements in 2008 and two years later to measure wall thickness of the Pipeline End Manifold (PLEM) and associated spool pieces subsea. The results in the paper include a comparison of wall thickness measurements conducted in several key areas. The results indicate wall thickness measurements conducted in 2010 for most of the measurement locations were similar to 2008 results except for several regions where the UT measurements were questionable based on erosion calculations. One major observation from UT measurements is that most measured wall thicknesses were less than the nominal wall thickness by 0.5 to 1.0 mm including sections where no flow was going through (no erosion/ corrosion) indicating absolute values of UT measurements can not be trusted with confidence unless calibrated subsea. Finally, the paper describes how UT measurements, erosion calculations, production controls and operation philosophy can be combined to maintain asset integrity and to control erosion of pipelines.