Day 4 Thu, November 15, 2018最新文献

{"title":"Enhanced Gas Recovery by CO2 Injection and Sequestration: Effects of Temperature, Vertical and Horizontal Orientations on Dispersion Coefficient","authors":"Muhammad Kabir Abba, A. Abbas, A. Al-Otaibi, G. Nasr","doi":"10.2118/192699-MS","DOIUrl":"https://doi.org/10.2118/192699-MS","url":null,"abstract":"\u0000 Enhanced gas recovery (EGR) by CO2 injection and sequestration is receiving increased attention within the research community. This is as a result of its potential to be an avenue for the simultaneous additional recovery of natural gas from the reservoir and provide a safe CO2 sequestration site. However, the major problem with this technology lies in the excessive mixing of the injected CO2 and the nascent natural gas (CH4) during the displacement process. This excessive mixing is the reason why the technology has not been widely patronised, given that the recovered CH4 will be heavily contaminated with the injected CO2 thereby making it \"lacking\" as sales gas after recovery. This hinders the market value of the recovered CH4 and eventually renders it not viable economically. Hence, highlighting the factors responsible for the mixing could provide technical solution to minimise the mixing phenomenon during EGR. This research focuses on the temperature effects and the orientation of the injection pattern of the technique. An experimental core flooding simulation was carried out at a temperature of 50°C and a pressure of 1300 psig and varying injection rates of 0.2 - 0.5 ml/min on Grey Berea sandstone core sample with the sample situated in both vertical and horizontal orientations. It was observed that at higher temperature (50°C) suitable for many gas reservoirs, the disperstion coefficient increased significantly compared to our earlier work (Abba, Abbas, & Nasr, 2017) at 40°C by a factor of 2.3. This trend was due to the increased energy of the gas molecules at the observed conditions, thereby increasing their mobilities. Conversely, the dispersion coefficient also increased significantly by a factor of 3.4 in the horizontal orientation at lower injection rates compared to the vertical core flooding with the concentration profiles showing significant capillary tailing effects at higher flowrates. This signified the effect of gravity in the horizontal orientation was more pronounced at lower injection rates during the injection of CO2 and this will have tremendous effect on the flow behavior of supercritical CO2 during the gas-gas displacement process.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76943700","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":"Well Placement Assessment Using Sequence Stratigraphic Zonation in a Complex Carbonate Reservoir","authors":"A. Salahuddin, K. Khan, R. A. Ali, K. Hammadi","doi":"10.2118/193057-MS","DOIUrl":"https://doi.org/10.2118/193057-MS","url":null,"abstract":"\u0000 The paper is continuation of our previous work published in the SPE-192896. This work illustrates horizontal well placement sensitivity analysis that was conducted on a complex Valanginian (Cretaceous) unsaturated oil carbonate reservoir with strong water drive. Existing producer wells are 80% horizontal and the remaining 20% are vertical to deviated producers. The production history is the approximately 20 years and currently a peripheral water injection is implemented, all injector wells are horizontals. The well placement is very challenging due to the presence of some thin high permeability streaks intervals with permeability value of up to 1 Darcy. Early water breakthrough encountered in the existing oil producers is a serious problem which results in lower recovery factor and costly lifting treatment. In addition, premature breakthrough would leave behind the potential oil accumulation. Therefore defining the optimum placement location of the producers is a crucial decision to be decided during well plan and field development.\u0000 In this paper we applied novel approach for stochastically modeling complex carbonate reservoir lithofacies and properties distribution using a pre-defined High Resolution Sequence Stratigraphy (HRSS) model subzonation. The key static geological elements that must be well defined are HRSS framework, lithofacies architecture, and field wide rock properties. In this study, we apply integrated geosciences, geostatistical, and flow simulations to assess options for well placement.\u0000 This new holistic approach has recently been successfully implemented in the studied field. The resulted geostatistical model was able to explain pressure depletion and production rate as shown in historical production data of the field. The resulting dynamic model will hence provide reliable production forecast and reservoirs development plan which will eventually allow accomplishing the mandate recovery target.\u0000 Flow simulation was used to analyze the performance of the well considering horizontal the well azimuth, well inclination, wells length, wells position relative to the sequence stratigraphic zonation, and well position relative to the water contact. In addition, multi-scenarios of well placement were created to see the impact on the oil rate, plateau, and water breakthrough time. Some producers in the studied reservoirs have been drilled using the multidiscipline study recommendation. Actual property and rate derived from the newly drilled wells displayed a very reasonable match to the expected property from the model.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77299672","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":"Complex Geological Modeling and Quality Assurance Using Unstructured Grids","authors":"S. Harris, Samita Santoshini, Sheleem Kashem, Thomas Viard, A. Levannier, Azeddine Benabbou","doi":"10.2118/193202-MS","DOIUrl":"https://doi.org/10.2118/193202-MS","url":null,"abstract":"\u0000 Conceptual limitations of existing gridding technologies often lead to undesirable simplifications to the modeling of structurally complex areas, and consequently poor predictions. We present a structural modeling and gridding workflow that limits these modeling compromises.\u0000 A volume-based 3D structural model based on fault and horizon surfaces is constructed from input data that has undergone basic quality checking using a variety of techniques. The critical step in the grid creation is the definition of a flattened (‘depositional’) space that deforms the structural model mesh under mechanical constraints. A 3D ‘unstructured’ grid is created in the depositional space, based on ‘cutting’ a property-populated, regular cuboidal grid by the geological discontinuities. The tectonic consistency and better preservation of geodetic distance make the flattened space ideal for a range of property modeling approaches. The forward-deformation of the grid into true geological space tends to preserve the layer-orthogonality of the grid columns and makes the grid more suited to numerical simulation approximations. The final grid is unstructured, high quality and an accurate representation of the input structural model.\u0000 The 3D structural model, depositional space transform and grid geometries all provide valuable information on the structural quality of the input data. The stretching and deforming of the orthogonal local axes in the transformation from depositional space to geological space are used to focus further effort on structural model quality assurance (QA). The key step in generating accurate property population and simulation models is the application of QA metrics on the grid geometry; the transformation from depositional space to geological space is used to generate a set of grid properties that highlight potential structural inconsistencies or data quality issues back in the structural model. We present several examples based on a range of structurally complex models, and demonstrate the downstream impact of applying this QA workflow throughout the stages of input data validation, structural model creation and grid creation.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"214 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74760605","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":"New Technology to Assist Drilling to Improve Drilling Rate in Unconventional Gas Resources: Pulsed Arc Plasma Shockwave Technology","authors":"Zhixiang Cai, Hui Zhang, Jun Li, Jiadong Zheng, Qing Yu, Kerou Liu, Yongsheng Liu","doi":"10.2118/193279-MS","DOIUrl":"https://doi.org/10.2118/193279-MS","url":null,"abstract":"\u0000 The rate of penetration is very low during the development of unconventional gas resources such as tight gas and marine shale gas, owing to high rock hardness and strength as well as heterogeneities at all scales. To improve the efficiency and reduce costs of developing unconventional gas resources, this paper proposed a new technology to assist drilling, Pulsed Arc Plasma Shockwave Technology (PAPST).\u0000 This technology converts electrical energy into mechanical energy to generate dynamic loads shockwave which can assist rock-breaking. Firstly, based on the fluid mechanics and bubble dynamics, the mechanism of shockwave generation was analyzed. Then, to verify the feasibility of PAPST technology, this paper conducted rock breaking experiment with shale samples from Longmaxi formation, China. Meanwhile, based on impact and damage mechanics, the mechanism of rock damage caused by dynamic load was analyzed.\u0000 The results show that shale samples were destroyed and there were cracks and collapse pits on shale samples after the impact of shockwave. Therefore, the application of PAPST technology to assist drilling is feasible, and the greater the discharge energy, the higher the efficiency of rock failure. Through theoretical analysis, it is found that the radial cracks of rock are caused by the tangential tensile stress, which is caused by the shockwave impacting the rock. The secant cracks are caused by the resultant force of the three component forces: the tangential and radial components of the force on the rock particle caused by the shockwave and the radial tensile force generated by the reflection of stress wave at the rock-water interface. The collapse pits are most likely caused by stress concentration.\u0000 For the first time, this paper proposed an idea of applying shockwave generated by PAPST to assist drilling for increasing the ROP in unconventional gas resources. And it also provided a theoretical basis for the application of PAPST in the field of oil drilling by analyzing the mechanism of shockwave generation in drilling fluids and the mechanism of rock breaking by shockwave.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"157 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73738217","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":"New Techniques Developed to Safely Unload and Test High Rate Offshore Sour Gas Well With 7-in Monobore Completions-Lessons Learned Gas Wells Offshore Sarawak Malaysia","authors":"Azraii Fikrie Azraii, A. Adhi, Thian Hui Chie Hui Chie, C. Claire, Ridzuan Shaedin Ridzuan, C. H. Roh, M. Z. M. Zarir, Firdaus Firdaus","doi":"10.2118/192815-MS","DOIUrl":"https://doi.org/10.2118/192815-MS","url":null,"abstract":"\u0000 Sarawak, Malaysia first offshore high rate dry gas field has an over pressured reservoir. Successful pressure control during drilling required the use of barite in the water based drilling mud in PMCD mode inside carbonate. Barite is very abrasive and is insoluble in any acid or solvent. Any barite left in the reservoir due to mud losses has to be produced back to surface after completing the wells. This cleanup is crucial for the safety and longevity of permanent facilities, especially when high rate gas wells are involved; due to the high rate of impact of any solids that may be produced with the gas. It is also critical to design the cleanup job carefully to ensure proper equipment and safety measures are taken to avoid washouts and related safety hazards.\u0000 To ensure solids free production from day one, a procedure was implemented and successfully executed during the development of this first offshore high rate high-pressure sour gas field. This was achieved by using the tender rig as a main support and complementing the safety with the incorporation of the selected well testing equipment management system. In addition to the proper equipment, a detailed cleanup procedure, which covered systematic production ramp up and defined solids free criteria, was implemented from well owner or asset. So far, this well cleanup setup and program has been implemented on several wells on platforms with minor erosion and no safety issues.\u0000 One platform with several wells is already producing and is flowing trouble free. This paper will describe the details of the setup of the rig facilities to clean these barite fluids from the wells, and the solids control equipment used and the cleanup procedure.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"21 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89614763","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":"Improved Decision Making for Coiled Tubing Well Intervention With Downhole Video Camera DVC","authors":"S. Hamid, A. K. Al-Mulhim, Abdullah A. Al-Ghamdi, V. Unnikrishnan, U. Ahmed","doi":"10.2118/192695-MS","DOIUrl":"https://doi.org/10.2118/192695-MS","url":null,"abstract":"\u0000 Conventional Coiled tubing well intervention has been carried out in oil and gas wells for more than 30 years with not real-time data acquisition. With the advent of Coiled Tubing Telemetry (CTT) e-line/fiber optics/mono conductors in coiled tubing industry, a wide variety of opportunities has become available - downhole video camera (DVC) being one of them, to go beyond the conventional parameters and optimize the well intervention operation.\u0000 DVC is used in the oil and gas industry with high success rate reported by several operating companies and service companies around the world. Video cameras have mostly been deployed using e-line; however, Coiled tubing camera runs provide the ability to clean the wellbore (by pumping fresh water or solvent) for capturing clearer, crisper videos and images.\u0000 As the oil and gas industry is moving towards improving operating efficiency, minimizing the coiled tubing runs based on actual downhole data is of utmost importance. Therefore, having the ability to inspect downhole obstructions using the video camera, and to observe the downhole conditions is phenomenal.\u0000 In this paper, the well intervention performed on multiple oil and gas wells in Middle East shall be discussed. Whenever an obstruction is encountered in the well bore, the primary form of detecting it is to run a lead impression block (LIB) on slickline or e-line. In most cases the LIB results do not provide a clear indication of the anomaly or obstruction. Not only that it sometimes adds to further confusion leading to inappropriate job design and planning, which results in potential misruns, inaccurate tool selection resulting in extensive and costly operations.\u0000 This paper aims to highlight the unique integration of DVC and telecoil application to enhance the reliability of data acquisition and job success. The custom designed downhole camera shroud, along with the robust CTT system is deployed in each of the candidate wells. The camera chosen is designed to withstand the maximum anticipated downhole temperature.\u0000 All the camera runs were analyzed and the obstruction in the wells was determined, which enabled the team of engineers to decide on the appropriate real-time course of action to gain access into the well bore or detect functionality of downhole jewelry.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"49 3 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89726690","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":"A Cost-Effective Dual-Element Metering System for Wet Gas Flowrate Measurement","authors":"Sami Halilah, K. Mokhtari","doi":"10.2118/192865-MS","DOIUrl":"https://doi.org/10.2118/192865-MS","url":null,"abstract":"\u0000 A wet gas flowmeter based on field-proven flowmeters and flow computers has been developed. The flowmeter is engineered by integrating the well-established SmartCone meter, a Pitot tube meter and filed mounted Flow Computer technologies in one wet gas metering solution. This combination exploits the characteristics of these two flow metering elements in wet gas flowrate measurement; The Cone measurement in wet gas is characterized by its relatively large gas measurement over-read with increasing liquid-loading, whereas this has a significantly lower impact on the gas flowrate measured by the Pitot tube.\u0000 The DynaCone wet gas flowmeter has been in development over the past several years with particular emphasis being placed on developing a flexible flowmeter for broad operating conditions and applications including high turndown ratio, minimal pressure loss, measurement quality diagnostic, and performance characterization in industry-recognized wet gas flow loop.\u0000 The wet gas performance has been demonstrated at CEESI wet gas flow loop yielding gas flowrates better than ±3% in Type I wet gas range, and better than ±5% in Type II without the input of liquid flowrate to correct for over-reading. Furthermore, uncertainties better than 2% and 3% for Type I & II respectively can be achieved if periodic liquid flowrate information is available for input.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"65 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86405853","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":"Gas Well Performance Analysis with Downhole Gas Compression","authors":"Cesar Montoya, Ahmed Aladawy, Ameen Malkawi, Rafael Adolfo Lastra Melo","doi":"10.2118/193310-MS","DOIUrl":"https://doi.org/10.2118/193310-MS","url":null,"abstract":"\u0000 Downhole gas compression is an artificial lift means that aims to increase production, maximize recovery and delay onset of liquid loading from gas wells. Being a technology not widely implemented yet, its application, benefits, operating window and limitations are not deeply managed by the oil & gas industry community.\u0000 The compressor boosts gas flow rates by increasing the pressure drawdown in the well proportionally to inlet pressure reduction. The required pressure ratio needs to meet the discharge pressure requirements to overcome well head pressure, column weight and pressure losses across the tubing, but the larger pressure ratio is the higher outlet temperature will be, which may become a limiting factor due to completion, compressor and process specs. Fluid velocity also varies across different casing sections, carrying with changes in liquid volume fraction (LVF) and flow regimes. In general, compressors are known to be low efficient handling liquids, therefore a close investigation on the LVF and flow patterns at inlet conditions must be very well understood for downhole applications.\u0000 Well modeling and sensitivity analysis will be used in this paper to illustrate in detail the well performance representation with downhole gas application along with a comparative analysis with surface gas compression to evaluate potential gains. Results and observations about these parameters, along with methodologies to calculate inlet/outlet conditions will also be described in this paper, adding to the existing literature a new holistic approach for analyzing gas well performance operated with downhole compressors.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"112 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86875260","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":"Targeting the Permo-Triassic Tight Gas in the Khuff: Lessons Learned in the Journey towards Development, Offshore Abu Dhabi, UAE","authors":"S. Steiner, Suvodip Dasgupta, M. Basioni, F. A. Aryani, A. Noufal, C. Mills, J. Mandl, Pradeep Menon, I. Raina, L. Mosse, S. Shasmal, F. Hollaender, Humair Ali, Baraka Al Afeefi, Neil Sookram","doi":"10.2118/192809-MS","DOIUrl":"https://doi.org/10.2118/192809-MS","url":null,"abstract":"\u0000 Exploration drilling for gas potential in Khuff Formation started more than 40 years ago and wells across multiple assets in offshore Abu Dhabi showed the presence of sizeable reserves. With increasing recent importance on gas production, there is a plan for moving towards development for those Permian tight gas structures to address the nation's gas needs. This paper will try to address the lessons learned from the recent appraisal wells in Khuff, the uncertainties and the success criteria.\u0000 There have been multiple wells drilled through the Khuff Formation in Offshore UAE in the last two years and have yielded a wealth of information from downhole well logs, mud logs, well test results and core data. The downhole logs acquired in these wells ranged from basic triple-combo and mud logs to image and dipole sonic logs, along with formation testing and sampling measurements, followed by well tests across the zones of interest. Interpretation of all these data have revealed some interesting lessons learned.\u0000 The shallow marine sequence of the Khuff Formation is generally characterized by poor porosity and low matrix permeability; however, the diagenetic overprint has resulted in a significant heterogeneity development, which controls the present-day porosity and permeability development at the wells. The well test results show variations in terms of 2 or 3 orders of magnitude at the same interval, which highlights potentially problematic development strategies. We have observed significant differences in terms of lithology, porosity and other reservoir quality indicators between wells, located a kilometre apart. Optimization of logging suite to minimize petrophysical evaluation uncertainty will be discussed. Characterising this heterogeneity is key for future economic success of this play. Possible role of fractures influencing flow from the Khuff have been discussed in older publications, however no conclusions were arrived at, with certainty. Presence of fractures and faults beyond the immediate vicinity of the well might be something to look at, in terms of understanding the potential productivity of those intervals. A big step for developing Khuff Formation might be in terms of deciding the optimal stimulation strategy and this is something, which remains to be studied extensively in UAE.\u0000 Closing the loop of interpretation of the acquired logs with the final well-test results and production logs gives us the advantage of hindsight and helps us in separating out the key productivity indicators as well as bring out the uncertainties in formation evaluation, which affect these tight gas reservoirs.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"122 2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89405388","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":"Operationalization of a New Systematic Work Process at PETRONAS Carigali Sdn Bhd","authors":"Amitava Choudhuri, M. S. Jainal, Mustafa B. Adenan, J. Takei, Toslan Ali, M. Janor","doi":"10.2118/192814-MS","DOIUrl":"https://doi.org/10.2118/192814-MS","url":null,"abstract":"\u0000 An innovative work process for integrated and collaborative way of working has been developed and is being operationalized throughout all PETRONAS Carigali operating blocks, within Malaysia and also, in all International Countries wherein PETRONAS Carigali is the operating partner. This process is inline to the Company's vision for a phenomenal shift in the way that the company's workforce accomplishes its tasks, employing latest digital technologies and efficient work processes. Through this work process, the intention is to integrate all systems and tools, adopt collaboration between various work disciplines and come up with a novel work process that is lean with the prime objective of maximizing production and improving the production efficiency.\u0000 This integrated and collaborative work process is being named as Reservoir Well Facility Management (RWFM), encompassing all the six production lenses and is thus an end-to-end business process. The geographical areas of operation of the Company are vast and scattered across the world. Thus, a need has been felt to standardize the work practices across all operating blocks in order to ensure that there is a standardized and integrated way of working at every work location. Also, there have been a number of digital solutions deployed over the last couple of years and the immediate need is to integrate all these solutions as well as to enhance their utilization. This RWFM work process will facilitate increased utilization of the tools as well as integrate all the current solutions.\u0000 The new work process has been deployed as a program at most of the Assets of the Company. The process will take some time to be fully practiced and the program team will be looking at a stabilization period before the Assets actively implement it in their daily routine. There is a Change Management effort ongoing in parallel to assist the operationalization team and to bring in the mind set change to inculcate the new way of working. This paper will entail a detailed discussion on the work process and the operationalization activity undertaken by the focused team.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"201 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80183082","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}