Day 3 Wed, September 26, 2018最新文献

{"title":"The Challenges of Deploying an MPD System on a MODU to Drill Narrow Margin Shallow Horizontal Wells in DW GoM","authors":"Sharief Moghazy, Keith Smelker, Julian Hernandez, R. V. Noort, M. Arnone","doi":"10.2118/191402-MS","DOIUrl":"https://doi.org/10.2118/191402-MS","url":null,"abstract":"\u0000 Managed Pressure Drilling (MPD) is an existing technology that is emerging in Deepwater drilling operations. This paper provides a case study from the Operator’s view, of preparing and deploying an MPD Surface Back Pressure (SBP) system for use in a shallow horizontal well with narrow drilling margins in 8,000ft water depth in the Gulf of Mexico.\u0000 This paper will describe the engineering, preparations and operational challenges of deploying a Below Tension Ring (BTR) MPD system. The paper will also include information on the hazard assessments, Mud Gas Separator (MGS) considerations, training plan, deployment plan and results, and engagement with the regulator.\u0000 The paper will present a case for the requirement of MPD for use in the narrow margin shallow horizontal wells, including an analysis of the required mud weights and surface back pressure to drill through narrow margins. It will also include a summary of best practices and lessons learned.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"48 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"131286040","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Measurement of Reduced Permeability at Fracture Face Due to Proppant Embedment and Depletion","authors":"O. Karazincir, Yan Li, K. Zaki, Wade Williams, Ruiting Wu, Yunhui Tan, Peggy Rijken, A. Rickards","doi":"10.2118/191653-MS","DOIUrl":"https://doi.org/10.2118/191653-MS","url":null,"abstract":"\u0000 Proppant embedment at the fracture face of a hydraulically fractured formation can result in reduced hydrocarbon flow from the matrix into the fracture due to reduced pore throat size, crushing of the rock, fines generation and pore plugging within the embedment zone (i.e. at the fracture face). Conventional proppant conductivity tests can only measure conductivity losses that occur within the proppant pack due to frac gel damage and compaction, not the damage at the fracture face. Test methods that can directly measure the effect of embedment on hydrocarbon production rates from a fracture are needed. A new test method that can measure proppant embedment at the fracture face as a function of different variables such as depletion, formation UCS and permeability, proppant type and loading has been developed. The same test method can also measure the resulting changes in the fracture-face permeability and the rate of fluid flow from the matrix into the fracture as a function of depletion, coupled with conductivity measurement within the proppant pack. A numerical model was built to provide reference solutions for the initial permeability.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"27 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114458341","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Enhanced Oil Recovery in Unconventional Liquid Reservoir Using a Combination of CO2 Huff-n-Puff and Surfactant-Assisted Spontaneous Imbibition","authors":"Fan Zhang, Imad A. Adel, Kang Han Park, I. Saputra, D. Schechter","doi":"10.2118/191502-MS","DOIUrl":"https://doi.org/10.2118/191502-MS","url":null,"abstract":"\u0000 Field observations, along with experimental laboratory, exhibit evidence that enhancing production by CO2 huff-n-puff process is a potential EOR technique that improves the, commonly low, ultimate oil recovery in unconventional liquid reservoirs (ULR). As pressure goes beyond the MMP, intermediate components of oil vaporize into the CO2 and consequently condense at room pressure and temperature. In addition, Surfactant-Assisted Spontaneous Imbibition (SASI) process has been widely believed to enhance oil recovery in ULR, which has been investigated by several laboratory and numerical studies. During the hydraulic fracturing with surface active additives, surfactant molecules interact with rock surfaces to enhance oil recovery through wettability alteration and interfacial tension reduction. The wettability alteration leads to the expulsion of oil from the pore space as well as water being imbibed into the matrix spontaneously. However, the understanding of hybrid EOR technologies, combining both gas injection and surfactant imbibition, to enhance recovery in ULR is not well studied.\u0000 In this manuscript, we assess the potential of combining both CO2 huff-n-puff and surfactant imbibition techniques in optimizing oil recovery in ULR. Sidewall core samples retrieved from ULR were first cleaned utilizing the Dean-Stark methodology and then saturated by pressurizing them with their corresponding oil for three months. CO2 huff-n-puff experiments were operated on shale core samples under different pressures in a set-up integrated into a CT-scanner. Those cores were then submerged in the surfactant solution, in a modified Amott cell, to observe whether any additional oil is produced through the process of SASI. Total production from these two different methods, which was done sequentially, will provide insight into the possibility of hybrid EOR technology. CO2 huff-n-puff experiments were performed below and above the MMP which was previously determined by the slim-tube method. Contact angle (CA), interfacial tension (IFT) were also measured on the saturated shale core samples. CT-Scan technology was used to visualize the process of oil being expelled from the core plugs in both CO2 huff-n-puff and spontaneous imbibition experiments.\u0000 Experimental results provide a promising outcome on the application of hybrid EOR technology, CO2 huff-n-puff and SASI, improving oil recovery from ULR. Oil recovery was observed to reach around 50% of measured OOIP from CO2 huff-n-puff alone with an addition of 10% recovery from SASI after the CO2 treatment. A detailed description of the correlated experimental workflows is presented to investigate the hybrid EOR technology in enhancing oil recovery in ULR. In addition, a discussion on the difference in mechanism of oil production from the huff-n-puff and SASI method is also included alongside several additional novel findings regarding the color shift of the produced oil. MMP data of CO2 and oil measured as well as a cha","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"144 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115859095","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Optimal 3D Reservoir Insight with a New Ultradeep-Reading Azimuthal LWD Resistivity Tool","authors":"A. Campbell, H. Beeley, M. Bittar, A. Walmsley, Junsheng Hou, Hsu-hsiang Wu","doi":"10.2118/191433-MS","DOIUrl":"https://doi.org/10.2118/191433-MS","url":null,"abstract":"\u0000 A new azimuthal electromagnetic (EM) logging-while-drilling (LWD) tool has been developed with multiple tilted antennas to measure three-dimensional (3D) electromagnetic fields. Multiple field trials successfully demonstrated the ultradeep detection range of more than 200 ft (60 m) with various transmitter-to-receiver spacings and operating frequencies, providing valuable geomapping insight for large-scale reservoir development. Additionally, this paper reveals the tool's capabilities in different geosteering applications, requiring different depth of detection (DOD) ranges for landing a well, optimizing well placement in thin reservoirs, and eliminating the need for a pilot hole.\u0000 This paper discusses in detail a new 3D finite-difference (FD) method to simulate realistic and complicated formation structures in three dimensions, enabling accurate formation interpretations and inversion of reservoir geology. Solving the scattered potential boundary value problem with the 3DFD numerical algorithm simulates the EM signals in this new LWD ultradeep application, and the modeling accuracy was benchmarked alongside in-house modeling codes and 3D commercial software. To accelerate the computation in the 3D modeling, sliding window, multicore parallel cloud computing, and decoupling between model pixel grid and FD simulation grid have been implemented for practical applications. Additionally, 3D modeling is used in the inversion to provide more accurate and complex reservoir determinations.\u0000 In addition to inversion, the tool provides 3D azimuthal multispacing, multifrequency geosignal, and resistivity measurements. Using the inversions and the 3D azimuthal images of the geosignal and resistivities enable improved reservoir understanding and geosteering decisions for the three dimensions. This paper describes two field trials from relatively thin to thick reservoirs to establish great and flexible geosteering performance because of multispacing, multifrequency measurements, and a robust signal and inversion process to optimize wellbore placements in the reservoir.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123008750","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Exploring Low-IFT Foam EOR in Fractured Carbonates: Success and Particular Challenges of Sub-10-mD Limestone","authors":"Pengfei Dong, M. Puerto, Guoqing Jian, Kun Ma, K. Mateen, G. Ren, G. Bourdarot, D. Morel, S. Biswal, G. Hirasaki","doi":"10.2118/191725-MS","DOIUrl":"https://doi.org/10.2118/191725-MS","url":null,"abstract":"\u0000 The high formation heterogeneity in naturally fractured limestone reservoirs requires mobility control agents to improve sweep efficiency and boost oil recovery. However, typical mobility control agents, such as polymers and gels, are impractical in tight sub-10-mD formations due to potential plugging issues. The objective of this study is to demonstrate the feasibility of a low-interfacial-tension (low-IFT) foam process in fractured low-permeability limestone reservoirs and to investigate relevant geochemical interactions.\u0000 The low-IFT foam process was investigated through core flooding experiments in homogenous and fractured oil-wet cores with sub-10-mD matrix permeability. The performance of a low-IFT foaming formulation and a well-known standard foamer (AOS C14-16) were compared in terms of the efficiency of oil recovery. The effluent ionic concentrations were measured to understand how the geochemical properties of limestone influenced the low-IFT foam process. Aqueous stability and phase behavior tests with crushed core materials and brines containing various divalent ion concentrations were conducted to interpret the observations in the core flooding experiments.\u0000 Low-IFT foam process can achieve significant incremental oil recovery in fractured oil-wet limestone reservoirs with sub-10-mD matrix permeability. Low-IFT foam flooding in a fractured oil-wet limestone core with 5-mD matrix permeability achieved 64% incremental oil recovery compared to water flooding. In this process, because of the significantly lower capillary entry pressure for surfactant solution compared to gas, foam primarily diverted surfactant solution from the fracture into the matrix. This selective diversion effect resulted in surfactant or weak foam flooding in the tight matrix and hence improved the invading fluids flow in it. Meanwhile, the low-IFT property of the foaming formulation mobilized the remaining oil in the matrix. This oil mobilization effect of low-IFT formulation achieved lower remaining oil saturation in the swept zones compared with the formulation lacking low-IFT property with oil. The limestone geochemical instability caused additional challenges for the low-IFT foam process in limestone reservoirs compared to dolomite reservoirs. The reactions of calcite with injected fluids, such as mineral dissolution and the exchange of Calcium and Magnesium, were found to increase the Ca2+ concentration in the produced fluids. Because the low-IFT foam process is sensitive to brine salinity, the additional Ca2+ may cause potential surfactant precipitation and unfavorable over-optimum conditions. It therefore may cause injectivity and phase trapping issues especially in the homogenous limestone.\u0000 Results in this work demonstrated that despite the challenges associated with limestone dissolution, a low-IFT foam process can remarkably extend chemical EOR in fractured oil-wet tight reservoirs with matrix permeability as low as 5 mD.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"121954646","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Integration of Dual-Porosity Modeling with 4D Seismic and Microseismic Technology in Niobrara and Codell Formations, DJ Basin","authors":"Yanrui Ning, H. Kazemi, T. Davis","doi":"10.2118/191682-MS","DOIUrl":"https://doi.org/10.2118/191682-MS","url":null,"abstract":"\u0000 This paper presents construction and validation of a reservoir model for the Niobrara and Codell Formations in Wattenberg Field of the Denver-Julesburg Basin. Characterization of Niobrara-Codell system is challenging because of the geologic complexity resulting from the presence of numerous faults. Because of extensive reservoir stimulation via multi-stage hydraulic fracturing, a dual-porosity model was adopted to represent the various reservoir complexities using data from geology, geophysics, petrophysics, well completion and production. After successful history matching two-and-half years of reservoir performance, the localized presence of high intensity macrofractures and resulting evolution of gas saturation was correlated with the time-lapse seismic and microseismic interpretations. The agreement between the evolved free gas saturation in the fracture system and the seismic anomalies and microseismic events pointed to the viability of the dual-porosity modeling as a tool for forecasting and future reservoir development, such as re-stimulation, infill drilling, and enhanced oil recovery strategies.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"51 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123432930","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"First Proppant Designed to Decrease Water Production","authors":"J. Green, Andreina Dewendt, J. Terracina, B. Abrams, Adam Harper","doi":"10.2118/191394-MS","DOIUrl":"https://doi.org/10.2118/191394-MS","url":null,"abstract":"\u0000 This paper discusses research on how proppant selection affects fracturing treatment results in shale formations that produce high water volumes. Fracturing treatments, formation characteristics, proppant types, and post fracture treatment production results are examined in detail. A production case study that focuses on the impact of proppant selection in wells completed in formations that produce hydrocarbons with a high water cut will also be presented.\u0000 This paper analyzes laboratory tests that were performed to measure the water and oil flow rates of various commonly used proppants. A case study on how Decreased Water Flow Proppant (DWFP) performed in the Granite Wash in the Texas panhandle is also highlighted. Post fracture treatment production results are compared to traditional proppants used in direct offset wells.\u0000 Laboratory testing showed DWFP had much lower water flow and higher oil flow through the proppant pack compared to traditional proppants. The results of the laboratory tests will be used to explain and support the production case study. The field case study proves that DWFP reduced formation water production, while increasing hydrocarbon production compared to traditional proppants used in offset wells. This innovative proppant appears to decrease the relative permeability to water in the proppant pack, resulting in lower water production and higher hydrocarbon production compared to conventional proppants.\u0000 This paper introduces the first proppant specifically designed for fracturing treatments in high water cut reservoirs. A new laboratory test method of measuring water flow rate through a proppant pack was specifically developed for this type of proppant. The proppant’s wettability is introduced as a new proppant selection factor for fracturing treatments in high water cut reservoirs.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"91 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128974238","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Pulsed Neutron Advances in Through-Casing Evaluation of Multilayered Reservoirs: Case Studies in the Mature Fields of the San Jorge Gulf Basin, Argentina","authors":"Daniel Maza, Fabian P. Oggier, Carlos Do Nascimento, P. Saldungaray, R. Zambrano, L. Mosse, Pablo B. Anci, Pablo Barrionuevo","doi":"10.2118/191535-MS","DOIUrl":"https://doi.org/10.2118/191535-MS","url":null,"abstract":"\u0000 An alternative technique to evaluate layered formations through casing in the Golfo San Jorge basin in Argentina is presented. The proposed methodology is based on pulsed neutron spectroscopy logs to assess the lithology and evaluate the hydrocarbon type and potential using resistivity-independent methods.\u0000 The basin's layered reservoirs present multiple challenges for resistivity-based methods, including low and variable formation water salinity, intricate pore systems affecting the rock electrical parameters, fine sediments with high irreducible water content suppressing the resistivity response, and high-resistivity tuffaceous sands not associated with hydrocarbons. In cased holes, simple correlations of resistivity and capture cross-section (sigma) or other techniques emulating openhole logs from basic pulsed neutron logs (PNL) can be used for interwell correlations, but are frequently inconclusive for assessing hydrocarbon potential. Our approach takes advantage of latest-generation PNL tools’ multiple measurements to reduce the uncertainty of water saturation assessment.\u0000 The proposed methodology was tested with two new-generation PNL tools, which feature high-resolution detectors that provide elemental concentrations for better understanding mineralogy including direct measurement of the carbon concentration for a reliable estimation of total organic carbon (TOC), which is directly associated with the oil volume in the pore space. The first tool was originally intended for openhole logging and has a single large detector for high-quality spectroscopy analysis. The second device is a multiple-detector slim PNL tool, which, besides the TOC and other spectroscopy outputs, also provides sigma and neutron porosity and measures a new property, the fast neutron cross section (FNXS), which is useful to detect and quantify gas. The presented case studies include examples of application with both tools in new wells and workovers. More than 20 sands, typically 2- to 5-m thick, interbedded with thick shales, were counted over the 1000- to 1500-m zone of interest, and all the data could be acquired in an acceptable time frame in spite the long intervals. The log data were complemented with the mud logging information and/or correlations from the static geological model. In all cases, we achieved good correlation between the zones with TOC, the static model, and well test results.\u0000 This experience illustrates the adaptation and application of new technologies to the development of mature fields where conventional openhole resistivity-based analysis is ambiguous. Future tasks include adjusting the technique for quantitative analysis and its use in deeper, more challenging, unconventional reservoirs in the basin.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"3 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"132209718","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Delivering Best in Class ROP Performance by Pushing the Operational Envelope with Novel Advanced Bit Designs","authors":"M. Armenta, M. Dykstra, Justin Muesel, E. Marshall, Takwe Yango, Olayinka Adeleye, M. Nagaraj, Mary Nasief","doi":"10.2118/191730-MS","DOIUrl":"https://doi.org/10.2118/191730-MS","url":null,"abstract":"\u0000 This paper describes the strategies and practices used to deliver best in class ROP performance in three different applications (through salt, soft clastic and medium-hard clastic formations) on the Deepwater Gulf of Mexico. A novel advanced bit design was tested with mechanical (WOB and RPM) and hydraulic (flow rate) parameters beyond the current operational envelope. Several operational and equipment limits were also tested and moved beyond the previous levels. The drilling parameters and results from the three applications are also included.\u0000 Over the last couple of years, the drilling cost for deep-water drilling has been reduced through continuous performance improvement resulting in a \"Beyond the Best\" mentality. Every time a new best in class ROP performance is achieved, questions about \"What else can be done\", are asked. A project was taken up to challenge the current drilling operational envelope resulting in ROPs faster than ever in the Deepwater Gulf of Mexico. Integrated well planning combining operator and service provider knowhow and modeling capability were used to identify current operational limits and the required changes to go beyond them. BHA configuration and downhole tools were design and adjusted accordingly. Rig equipment were also reviewed and modified. The novel advanced bit design, with 3D cutting elements combining the shearing action of conventional PDC cutters with the crushing action of tungsten carbide insert, was selected by the project due to its capability of delivering less torque when higher mechanical parameters (WOB and RPM) are used.\u0000 Field data demonstrates that using WOB up to 70,000 lbs while drilling with a 14-3/4\" bit through medium-hard rock resulted in 9 % increase in ROP (103.2 ft/hr), when compared with the previous fastest ROP achieved while drilling similar formations in the field. Also, using 220 rpm while drilling trough salt with a 16-1/2\" bit delivered 12% increase in ROP (307.3 ft/hr), when compared with the previous best performance. Furthermore, using 220 rpm in combination with 1460 gpm flow rate (22% above the normal flow rate), while drilling with a similar 16-1/2\" bit through interbedded soft rock formations delivered 91% increase in ROP (368.7 ft/hr), when compared with the previous fastest ROP achieved while drilling similar formations in the field. The cuttings load limit in the annulus was tested beyond its current limit (3%) without observing hole pack off or stuck pipe issues. No vibration was observed while operating at the surface torque limit. A cost saving of over $2M was realized from this performance improvement effort.\u0000 The identified opportunities for improvement and lessons learned included in the paper have led to best practices for future wells resulting in a valuable benchmark benefiting practicing engineer involved in similar projects. Furthermore, operational parameters used in the project confirm the robustness and benefits of the novel advanced bit design used i","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"2016 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"127538455","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"The Benefits of Reciprocal Mentoring in the Oil and Gas Industry","authors":"L. Dalrymple, E. D. Dalrymple","doi":"10.2118/191761-MS","DOIUrl":"https://doi.org/10.2118/191761-MS","url":null,"abstract":"\u0000 \u0000 \u0000 As the Oil and Gas industry looks for ways to better manage its increasingly age diverse workforce, reciprocal mentoring (RM) has become a necessity. Industry veterans are nearing retirement. Young entrants to the workforce are knowledgeable in technology, but lack industry experience. These two circumstances, along with other factors, helped create the perfect storm – the Great Crew Change.\u0000 RM can pave the way for a new standard of open dialogue in business, stretching far beyond technology. Ideally, learning and information sharing would cross all lines of seniority and responsibility.\u0000 \u0000 \u0000 \u0000 Everyone knows that mentoring can be useful to a young employee. However, there is a lot that junior employees (millennials) can offer as mentors themselves. Senior employees were trained when technology transfer was slower and less sophisticated. They learned to give presentations without the aid of PowerPoint and other media available today. Often, they relied on a flipchart for a presentation, so they have well developed soft skills and interpersonal skills. Millennials recently graduated, have more experience in technology transfer, and recent applications and technology developed, and are more inclined to communicate through email, text, and social media. RM acts as a powerful tool to help both junior and senior employees strengthen specific skills.\u0000 \u0000 \u0000 \u0000 Reciprocal mentoring can create dynamic teams utilizing the overall strengths of both millennials and senior employees. These two-way conversations become avenues where employees can discuss insights from both perspectives and gain valuable knowledge from one another in an environment of trust. With the increasing number of Millennials joining the workforce in the oil and gas industry, management must incorporate new ways of mentoring them. The increase in the age gap between senior employees and millennials creates a challenge to keep the workforce engaged.\u0000 \u0000 \u0000 \u0000 Differences in perspective, attitude towards work and different motivation can result in friction and an unwillingness to collaborate. This is the role of reverse mentoring which is detailed in this paper. With the \"Big Crew Change\" we are experiencing a shortage of younger more experienced technical professionals. Reciprocal mentoring is a way to bridge that gap.\u0000","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126294093","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}