Spe Production & Operations最新文献

{"title":"Design and Analysis of a New Profile Control Tool: Swirling Autonomous Inflow-Control Device","authors":"Yang Mingjun, Wu Xinyuan, Yue Yingchun, Z. Ying, Ye Chen, Yufeng Tang","doi":"10.2118/199364-pa","DOIUrl":"https://doi.org/10.2118/199364-pa","url":null,"abstract":"\u0000 Edge/bottomwater cresting or even breaking into the wellbore has been a major factor affecting crude-oil production and has not been overcome so far. Aiming at this problem, this paper designs a new autonomous inflow-control device (AICD) profile control tool—swirling AICD—on the basis of the research of profile control tools used in the past. The AICD is mainly based on the principle of automatic phase separation, the splitting of three-way pipes, and the principle of vortex depressurization. Combined with the special flow path, the production of edge/bottomwater can be effectively restrained. Computational fluid dynamics (CFD) numerical simulation and indoor flow experiments are used to prove the water-control function of the swirling AICD, to obtain the pressure and velocity distribution of fluid flow in the AICD, and to obtain the influencing factors and their influence rules. Based on these analyses, we established the swirling AICD mathematical model, which has laid a theoretical foundation for the application of swirling AICDs in wells.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/199364-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49607695","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"A Holistic Approach in Establishing a Structured Framework to Maximize Production Availability through Integrated ESP Key Performance Indicators","authors":"Ahmed A. Al-Khalaf, S. Alquwizani, Hashim Al-Sadah, Cleavant Flippin","doi":"10.2118/192459-pa","DOIUrl":"https://doi.org/10.2118/192459-pa","url":null,"abstract":"\u0000 Managing large-scale electrical submersible pump (ESP) operations and assessing their performance can be a challenging task. Diverse operational environments, widely spread geographical areas, large ESP populations, and different service providers are some of the complications facing operators. Nonetheless, it is vital to the success of any artificial lift project to establish a performance evaluation structure that can effectively capture deficiencies and highlight improvements.\u0000 While many operators focus on run life statistics as the central key performance indicator (KPI) for ESPs, these types of statistics may not be sufficient in providing meaningful information to decision makers. Other important ESP performance parameters include ESP shutdowns (both planned and unplanned), restart time of tripped ESPs, commissioning time, failure rate, and the number of premature ESP failures. Thus, a comprehensive study was jointly initiated between an oil operator and ESP vendors to establish KPIs that drive improvements in all aspects. The selected KPIs were developed in a structure that ultimately focuses on maximizing production availability and revenue generation.\u0000 By constructing the ESP KPI framework, subpar performance areas were clearly visible by both the operator and the service provider. Decision makers were able to identify and act on fields that lag in performance while exerting efforts to improve underperforming service providers. Furthermore, regular meetings were conducted to review the established KPIs and recommend some action items, which might focus on either technical or operational solutions. Finally, KPI targets were set on the basis of the review of historical trends and were assigned to be challenging yet relevant and attainable. The followed practice can prove to be successful in forming a common ground where service providers can quantify losses by the operator as a result of ESP performance deficiencies.\u0000 Comprehensive data collection and keeping of ESP trips, failures, and replacements are critical to the success of this work. Regular review of field reports and well performance are imperative to accurately compute the various KPI formulas. In fact, many of the KPI calculations can be automated to capitalize on the available communication networks installed in the field to improve ESP monitoring and accurately assess their performance.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/192459-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46754209","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Water Shutoff with Polymer in the Alvheim Field","authors":"K. Langaas, A. Stavland","doi":"10.2118/195485-pa","DOIUrl":"https://doi.org/10.2118/195485-pa","url":null,"abstract":"\u0000 The Alvheim Field, offshore Norway, has subsea wells with long horizontal branches completed with sand screens. After 10 years of production, water production starts to constrain the oil production. Mechanical water shutoff is not possible in these wells; hence, other methods are of interest. In a well workover in 2013, two high-viscosity polymer pills were bullheaded and squeezed into the reservoir. The well productivity was reduced by approximately 50% and the water cut dropped, suggesting potentially higher oil recovery. A research study was started with the objectives of understanding the changed well performance and whether polymer bullheading can be a future method to reduce water production and enhance oil production.\u0000 An experimental laboratory program started with filtration tests of polymer solutions on the basis of the polymer used in the well operation. Coreflood experiments were performed by injecting polymer into two parallel-mounted cores and then back producing these individually with either water or oil. Several combinations of parallel cores were tested with polymer injection: high vs. low permeability, high oil saturation vs. low oil saturation, outcrop sandstone vs. Alvheim core, and two different polymer formulations.\u0000 The polymer formulation as used in the well operation demonstrated the plugging of standard filters with filter size larger than the reservoir pore sizes, but it did not plug the cores. The polymer formulation as used in the well gave a better disproportionate permeability reduction (DPR) than the alternative polymer variant with similar viscosity. A theoretical model for the shear rate in the porous media matched the experimentally measured data excellently. The core results show a stable permeability-reduction factor of 100 to 450 for water, while a factor of only 2 to 10 and decreasing with time for oil. The achieved DPR ratio of 45 to 80 is better than the trend from earlier published results.\u0000 The DPR as measured in the laboratory was next integrated into the reservoir model as part of the history match of the treated well. The Alvheim field has several reservoir zones separated with thin shales, and this reservoir zonation seems key for this enhanced-oil-recovery (EOR) method to work.\u0000 The laboratory work, the reservoir studies, and the field experience all point to a possible robust and simple EOR method for Alvheim and similar oil fields. Future work includes more research and maturing a new polymer pilot on Alvheim.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/195485-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46186159","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"An Experimental Approach To Assess the Dispersion of Shale in Fracturing Fluids","authors":"I. A. Muggli, K. Chellappah, I. Collins","doi":"10.2118/197044-PA","DOIUrl":"https://doi.org/10.2118/197044-PA","url":null,"abstract":"\u0000 We propose an experimental approach to evaluate how typical fluids influence shale dispersion. In this approach, finely ground shale is left to settle in the fracturing fluid, generating particle-size and concentration profiles within the settling column. Samples are taken at various settling times and depths and then analyzed with regard to turbidity and capillary-suction-time (CST) behavior. Particle-size-distribution (PSD) measurements are used to further substantiate analysis. Turbidity data indicate the volume of particles present, and PSD data indicate the sizes of these particles (or flocs). This approach was tested using ground shale, Eagle Ford brine (EFB), and three typical fluid additives. Without additives present, shale flocculation resulted in rapid particle settling, and samples taken from suspension gave low turbidity and CST values. With additives present, suspensions were better dispersed and hence tended to give higher CST values. Some additives hindered flocculation more effectively than others. The results suggest that low CST numbers might not always be desirable; additives that are good inhibitors might hinder flocculation of shale particulates and hence promote higher CST numbers. In this paper we discuss how our proposed experimental approach can give insights into the influence of additives on the degree and nature of shale dispersion.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/197044-PA","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47286485","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Development and Efficiency Testing of Sucker Rod Pump Downhole Desanders","authors":"C. Langbauer, M. Hartl, Sergej Gall, L. Volker, Christian Decker, Lukas Koller, S. Hönig","doi":"10.2118/200478-pa","DOIUrl":"https://doi.org/10.2118/200478-pa","url":null,"abstract":"\u0000 Tense economic situations push the demand for low-cost oil production, which is especially challenging for production in mature oil fields. Therefore, an increase in the meantime between failure and the limitation of equipment damage is essential. A significant number of wells in mature fields are suffering under sand by-production. The objective of this paper is to show the development process and the testing procedure of an in-house-built, effective downhole desander for sucker rod pumps on the basis of a sophisticated analytical design model.\u0000 In weak reservoir zones, often the strategy to prevent equipment damage due to sand by-production is the sand exclusion method using a gravel pack. Nevertheless, a certain amount of small sand grains still enter the wellbore and may damage the sucker rod pumping system over time. In early 2018, various types and sizes of downhole desander configurations were tested at the pump testing facility (PTF) at the University of Leoben (Montanuniversitaet Leoben). In a period of about 4 months, testing took place under near field conditions to find the optimum and most efficient design. The design optimization was focused on the geometry of the swirl vanes and the sand separation distance at the sucker rod pump intake. An analytical model provided the basis for geometric optimization. Concurrently, field tests of the in-house downhole desander were performed in the Vienna Basin that confirmed the findings of the tests at the PTF.\u0000 The test results have shown that the downhole desander design and the pumping speed are the most influencing parameters on sand separation efficiency. Poor design in combination with a wrongly selected pumping speed can reduce the sand separation efficiency to lower than 50%, while if all parameters are chosen correctly, the sand separation efficiency can be 95% or higher. The grain size distribution is the additional parameter that enables a decision and ranks the performance. The sensitivity analysis, performed for several downhole desander types, has shown the high dependency of the sand separation efficiency on the major desander design parameters. Proper selection of the components and operating parameters will contribute to an increase in the meantime between failures.\u0000 This paper will present the testing configurations, the development of the high-efficiency in-house downhole desander, and the sensitivity analysis performed on the design.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/200478-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46039594","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Use of Far-Field Diverters To Mitigate Parent- and Infill-Well-Fracture Interactions in Shale Formations","authors":"Junjing Zhang, D. Cramer, Jamie McEwen, M. White, K. Bjornen","doi":"10.2118/194329-PA","DOIUrl":"https://doi.org/10.2118/194329-PA","url":null,"abstract":"\u0000 Hydraulic-fracturing treatments in shale infill wells are often impacted by existing parent-well depletion and asymmetrical fracture growth. These phenomena can result in excessive load-water production, deposition of proppant and deformation of casing in the parent well, and unbalanced stimulation of infill wells. This study determines the effectiveness of particulate materials (i.e., far-field diverting agents) for mitigating the above negative outcomes by bridging near the extremities of dominant fracture wings.\u0000 Fracture propagation was modeled to characterize the width profile at fracture extremities in a depleted-stress environment. A slotted-disk device was used to evaluate and optimize particulate blends for bridging slots representative of width near the fracture tip. Rheological tests replicating the downhole environment were used to formulate a system for transporting the diverting materials. Statistical analysis of 511 fracture hits at 30 parent wells was performed on key treatment indicators by the category of diverter type and post-hit parent-well condition. Production trends of the influenced wells were compared to area-specific type curves and offset wells without diverter trials.\u0000 On the basis of the simulation and testing results, two types of high-graded far-field diverter systems were field-tested in a shale play: dissolvable, extremely fine particulate mixed with a 100-mesh sand, and mixtures of a nominal 325-mesh silica flour and a 100-mesh sand. Proppant dust collected at the fracturing site was also evaluated for replacing commercial silica flour. High-graded blends of the above diverting systems demonstrated superior fracture-hit and productivity metrics as compared to the base case of not applying far-field diverters. The silica flour and 100-mesh-sand mixture performed on a par with the significantly more expensive blend of dissolvable fine particulate and 100-mesh sand. Borate-crosslinked-guar gel was an effective carrying fluid for transporting diverting materials to the fracture extremities.\u0000 Statistical analysis of fracture-hit events shows that the application of far-field diverters did not reduce the magnitude of pressure buildups during fracture hits; however, it significantly increases the post-hit pressure-falloff rate at the parent wells. On the basis of the area-specific type curves, pumping far-field diverters increased the P50 estimated ultimate recovery (EUR) by approximately 6% compared with the base cases of not applying diverters. For all the wells impacted by far-field diverters, the infill wells saw larger benefits with an increment of P50 EUR by approximately 7% compared with the parent wells.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-05-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/194329-PA","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"46991821","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Height Growth in Layered Unconventional Reservoirs: The Impact of Formation Moduli, Interfaces, and In-Situ Stress","authors":"Q. Gao, A. Ghassemi","doi":"10.2118/201104-PA","DOIUrl":"https://doi.org/10.2118/201104-PA","url":null,"abstract":"\u0000 In recent years, much research effort has focused on hydraulic fracture (HF) height growth because height containment is needed to ensure effective stimulation of target zones. In many cases, fracture height growth determines the success or failure of a hydraulic stimulation. For layered rock systems, material properties, interface mechanical characteristics and permeability, and in-situ stresses influence both the lateral and height growth of HFs. It is generally believed that stress contrast is a dominant factor that directly controls the fracture height. The influence of Young's modulus contrast on height growth is usually ignored. Simplified “average methods” are often proposed and used to homogenize layered modulus. Also, it is commonly assumed that the layer interfaces are perfectly bonded without slippage even when high stress contrast exits. The above assumptions are made partially due to the difficulty in handling all the factors (e.g., layered modulus and stress contrast between adjacent layers) involved in simulations. In this study, a fully coupled 3D HF simulator that is based on the finite element method (FEM) is used to investigate the above factors and study how they impact HF propagation and height growth. The influence of modulus contrast, interface conditions, and in-situ stress on hydraulic fracturing and especially on fracture height growth is analyzed.\u0000 The numerical approach is a 3D FEM with a special zero-thickness interface element based on the cohesive zone model (CZM) to simulate the fracture propagation and fluid flow in fractures. A local traction-separation law with strain-softening is used to capture tensile cracking. The nonlinear mechanical behavior of frictional sliding along interface surfaces is also considered. Because discontinuities are explicitly simulated through using the interface elements, details of the deformation processes are captured and revealed. For example, information related to aperture opening/sliding and stress distribution along the discontinuities is obtained in the simulations. After verification and validation of the numerical model, it is used to simulate height growth in layered rock of practical interest. The numerical model is evaluated through a commonly used crossing/arrest criterion. Laboratory experiments on fracture-discontinuity interaction under triaxial stress conditions are also studied. Numerical results match well with predictions from theoretical formulations and with laboratory observations. Typical processes associated with fracture-discontinuity interaction are revealed. The recorded injection pressure increases when the HF reaches a bedding interface (or other discontinuities). Continuous opening and/or sliding along the interface requires higher injection pressure. With the existence of a horizontal interface, the influence of modulus contrast and stress contrast on HF height growth is analyzed. The combined effects of rock properties, mechanical properties of the ","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-04-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/201104-PA","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47461331","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Material Overview for Electrical Submersible Pumps: Part II—Polymeric and Other Materials","authors":"J. Xiao, R. Lastra, B. A. Roth, Wee Sun Lee","doi":"10.2118/198911-pa","DOIUrl":"https://doi.org/10.2118/198911-pa","url":null,"abstract":"\u0000 Electrical submersible pumps (ESPs) are a key artificial-lift technology in the petroleum industry. Worldwide, installed ESPs in oil wells are in the range of 130,000 units, contributing to approximately 60% of the total oil production in the world. An ESP is made up of hundreds of components integrated to perform the lifting function. Materials in these components belong to several categories, including metals, ceramics, polymers, and others. A good understanding of these materials and vigilant selection for a specific application are critical to the reliability and run life of an ESP system. This series of papers provides an overview of all major classes of materials used in ESP systems. It is intended to serve as a reference for ESP field-application engineers who are responsible for the design, equipment longevity, and production optimization. This paper focuses on polymers and other materials.\u0000 The information compiled in this paper is the result of an extensive literature review. We cover materials used in the motor, protector, pump, and cable (sensor, packer, Y-tool, diverter valve, surface components of variable-speed drives, and transformer are not included). For each class of materials, we identify relevant material properties and discuss suitable application conditions.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/198911-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"47838071","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Transient Wellbore-Pressure-Buildup Correlation Helps Engineers To Ensure HIPPS Safe Operation","authors":"Ahmed Homoud, R. Gajbhiye, Dhafer Al-Shehri","doi":"10.2118/199342-pa","DOIUrl":"https://doi.org/10.2118/199342-pa","url":null,"abstract":"\u0000 The objective of this study is to develop a correlation for transient wellbore-pressure buildup and relate it to the high-integrity pressure-protection system (HIPPS) response time in multiphase flow. The developed correlation gives an accurate estimate of the pressure buildup with time under shut-in conditions. It provides guidelines to set the HIPPS activation pressure considering different reservoir and wellbore parameters to ensure the safety and timely response of HIPPS.\u0000 The correlation was developed by performing transient simulations to calculate the wellbore-pressure-buildup time under shut-in conditions accounting for different reservoir and wellbore parameters. The input data were gathered from three oil fields with various fluid properties, reservoir pressures, productivity indices (PIs), depths, and shut-in wellhead pressures (SIWHPs). Before feeding the data to the dynamic flow simulator, the reservoir data were tuned to match the well-flow conditions. After completing the transient simulation for every well, the pressure-buildup data as a function of time were collected and used as input to develop a correlation using the nonlinear-regression method.\u0000 The results of this study show that the most influential parameters on the pressure-buildup behaviors are fluid compressibility, PI, flowing wellhead pressure (FWHP), and well measured depth (MD). In addition, we observed that there is a strong relationship between the fluid compressibility at FWHP condition and the time it takes to pressurize the wellbore to maximum pressure. The higher the fluid compressibility, the longer it takes the system to pressurize. The newly developed correlation provides a guideline for setting the HIPPS activation pressure and ensuring the wells’ safe operation.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/199342-pa","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49058838","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integrated Approach Toward Diagnosing Microbiologically Influenced Corrosion in the Petroleum Industry","authors":"P. Bruijnen, W. van Strien, Sabine Doddema","doi":"10.2118/197059-PA","DOIUrl":"https://doi.org/10.2118/197059-PA","url":null,"abstract":"\u0000 The microbiologically influenced-corrosion (MIC) -related problems encountered in the water-injection wells of the Rijn Oil Field, offshore the Netherlands, were assessed from multiple perspectives to determine the root cause of the corrosion and the declining injection performance. Various classical petroleum-engineering methods were combined with full-bore electromagnetic inspection and 3D laser scanning of tubing sections to analyze the injectivity and integrity problems on both well and reservoir scales. Quantitative evaluation of materials by scanning electron microscopy (QEMSCAN), a novel technique for quantitative analysis of minerals, was used to identify chemical components in the corrosion products and allowed us to reconstruct the electrochemical processes that had taken place on a micrometer scale. Molecular microbiological methods (MMMs) such as quantitative polymerase chain reaction (QPCR) and 16S next-generation sequencing (NGS) were applied to identify the entire microbial population in various samples.\u0000 Petroleum engineering, corrosion engineering, and microbiology were thus combined in a multiscale and multidisciplinary approach. This approach was followed successfully during the diagnostic process, resulting in verifiable hypotheses about the fundamental corrosion and plugging mechanisms in these water-injection wells. The results confirmed that the dominant corrosion process was MIC. Also, the presence of chloride contributed significantly to the corrosion process, possibly in combination with underdeposit corrosion (UDC). The full suite of analyses shed light on possible causes of the declining injectivity in the wells: There appeared to be a link between the formation of deposits and corrosion, strongly influenced by microbes. In this paper we demonstrate the importance of an integrated approach, which can lead to reliable diagnostics and successful mitigation against future corrosion and the declining performance of wells and pipes.","PeriodicalId":22071,"journal":{"name":"Spe Production & Operations","volume":null,"pages":null},"PeriodicalIF":1.2,"publicationDate":"2020-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.2118/197059-PA","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"49294432","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":4,"RegionCategory":"工程技术","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}