Day 3 Wed, September 26, 2018最新文献

{"title":"Excelling Asset Design: Performance and Operation Management Utilizing Reservoir-Production-Processing Facility Integrated Modeling Approach","authors":"Carlos M. Yengle, H. Kumar","doi":"10.2118/191485-MS","DOIUrl":"https://doi.org/10.2118/191485-MS","url":null,"abstract":"\u0000 Asset steady-state modeling is frequently done by separate teams of engineers working on asset subsystem, production, and processing facility design and asset operation management. Design criteria shared between the teams are based on a limited set of predefined discrete assumptions for each subsystem. Currently, the commonly used modeling approach fails to account for subsystem interdependencies and does not enable assessment of changing conditions across the asset life cycle. This gap often results in suboptimal facilities design for the asset and cost overruns and/or lost production. Overall asset management decision-making tools should be based on reinforcing the consistence of information used across the whole asset. Integrated modeling helps to make informed decisions by considering the combined effect of reservoir uncertainties, well placement, surface network, and process facility on overall asset design, production, and management. This paper describes how a full integrated asset model is built and used as an effective decision support tool to help optimize overall asset design and operational performance management.\u0000 A full integrated model is built using typical industry-known commercial simulator packages for each subsystem and field conditions. It includes steady-state models for reservoirs, wells, production and injection networks, and processing facilities. A platform, which orchestrates data connectivity and integration while allowing subsystem applications to maintain their dependency in thermodynamic properties and equations of state solving, is used for transferring data and controlling variables within the subsystems. Data from a major capital project in the early stages of development were used to pilot test the technique and stress test the consistency of forecast production across the subsystems for whole asset impact due to a change in an individual subsystem such as reservoir uncertainties, well placement and scheduling, surface network operating conditions, and individual subsystem constraints.\"\u0000 The integrated multifield network model provided realistic optimal operating conditions and long-term production forecasts of oil production, sales gas, and water injection requirements by incorporating the physics at appropriate levels to ensure higher accuracies than discrete models.\u0000 Integrated asset modeling uses information consistently across the entire asset and includes subsystem interdependencies on overall asset steady-state operating conditions. Integrated modeling provides the opportunity for independent teams of facilities engineers, production engineers, and reservoir engineers to collaborate as a unified team while maintaining specific expert's needs and resources.\u0000 The asset integrated model technique offers a novel and versatile capability of evaluating diverse operational scenarios to find optimal settings for short- and long-term asset production needs.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"13 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":"123605167","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":"Design of Offshore Production Systems Considering Uncertainties","authors":"Leonardo Sales, C. Morooka","doi":"10.2118/191507-MS","DOIUrl":"https://doi.org/10.2118/191507-MS","url":null,"abstract":"\u0000 The development of an offshore oil field is a complex and risky project. One core problem in this task is the selection of a production system that maximizes oil recovery and minimizes investments and operational costs while meeting external, economic, environmental, societal and technological demands in a scenario of uncertainties. Several studies address this problem in the literature; however, they do not consider uncertainties in the initial data neither justify objectively the chosen alternative among other feasible ones. We propose to select an offshore production system using an intelligent system that considers input uncertainties and chooses the best alternative in a rational manner. By comparing the results obtained with previous studies and real scenarios, we conclude that our methodology can obtain the optimal solution in situations where other methods cannot.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"23 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":"121936953","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":"Streamline Tracing and Applications in Naturally Fractured Reservoirs Using Embedded Discrete Fracture Models","authors":"Hongquan Chen, Tsubasa Onishi, Feyi Olalotiti-Lawal, A. Datta-Gupta","doi":"10.2118/191475-MS","DOIUrl":"https://doi.org/10.2118/191475-MS","url":null,"abstract":"\u0000 The streamline based technology has proven to be effective for various subsurface flow and transport modeling problems including reservoir simulation, model calibration and optimization. For naturally fractured systems, current streamline models are well suited for dual porosity single permeability systems because streamlines need to be traced only for the fracture system. However, complications arise for dual porosity dual permeability (DPDP) systems because streamlines need to be traced for both fracture and matrix systems. Also, the streamlines in the two systems may interact. We present a robust streamline tracing framework for use in the DPDP models via an embedded discrete fracture model (EDFM) framework.\u0000 The EDFM models utilize irregular gridding and non-neighbor connections to explicitly represent the discrete facture network. Our strategy is based on a boundary layer method that can be used to honor the fluxes at the matrix-fracture interface during streamline tracing. We generalize our previously proposed streamline tracing algorithms for local grid refinements (LGR) and faulted systems to discrete fracture network models where a fracture gridblock in EDFM is treated as a boundary layer for flux continuity and streamline tracing. The proposed method is benchmarked with a semi-analytical solution and a series of numerical examples encompassing different levels of geologic and geometrical complexity to illustrate the accuracy and robustness of the approach. Visualization of streamlines in complex fracture networks provide flow diagnostics such as sweep efficiency and connectivity of wells and fractures. The streamlines are then utilized to develop a workflow for rate allocation optimization for waterflood in naturally fractured reservoirs. We utilized a streamline-based gradient free algorithm whereby both injection and production rates are adjusted under realistic operational constraints. This approach only requires a few forward simulations and therefore offers significant advantages in terms of computational efficiency. It is confirmed that the optimized schedule provides improvements in oil recovery and sweep efficiency compared to the base scenario with uniform injection and production rates.\u0000 The uniqueness of this work is the robust streamline tracing algorithm in the EDFM using a novel boundary layer based approach for flux continuity. The proposed approach is simple and easy to implement and can be coupled with commercial simulators for field scale applications.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"10 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":"131566365","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":"Young Researcher Program: Developing Today's Innovators and Tomorrow's Leaders","authors":"S. Kokal","doi":"10.2118/191605-MS","DOIUrl":"https://doi.org/10.2118/191605-MS","url":null,"abstract":"\u0000 Is your education and training complete after you graduate from university? In today's competitive world, the answer is a resounding \"no.\" Success in your career requires that you create a plan, take advantage of all the resources and opportunities to hone your skills, and continue to learn. That is part of the motivation for the development of the Young Researcher Program (YRP) at Saudi Aramco's Advanced Research Center (EXPEC ARC), the company's upstream research and development center.\u0000 The program was established with the objective of developing self-motivated and innovative researchers who lead in their area of specialty and support the company's vision, mission and strategic goals. It provides an opportunity for qualified engineers and geoscientists to become engineering/scientific specialists and, at the same time, provides the company with advanced technical expertise in the specialties for which there is a critical need. The program has a clear structure with distinct phases, and qualified candidates are matched with the most appropriate mentors. This strategy ensures that the young researchers obtain the required experience, further education and exposure for their chosen specialty. The program provides a roadmap for optimizing the professional growth and advancement of candidates. The program is sufficiently flexible to respond to candidates' training and work requirements, and enables them to achieve higher levels of competence and productivity. An important part of the program is the close relationship between the mentee and their mentor.\u0000 This paper will highlight the main features of the unique and successful program to develop young researchers. It will describe the program, roles and responsibilities of various entities, graduation requirements and its tracking and evaluation. It presents a success story that can be the basis for others to follow.","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":"129971355","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":"Successful Adoption of New Technology: Implementation of a Global Drilling Bit Dysfunction and BHA Vibration Initiative","authors":"J. Willis","doi":"10.2118/191736-MS","DOIUrl":"https://doi.org/10.2118/191736-MS","url":null,"abstract":"\u0000 Previously published technology that was not used in a company was implemented using a new approach based on marketing technology that resulted in widespread adoption and a lasting change. The drilling technology was available for years in SPE papers. Previous attempts to implement it failed to establish lasting application. The initiative took about two years and resulted in the use of the technology being well established. In addition to the process used to implement the initiative, the drilling technical process is also summarized.\u0000 The initiative drove implementation of the use mechanical specific energy (MSE) and other techniques to identify and minimize bit dysfunction and bit and bottomhole assembly vibrations. Full implementation of the techniques required drilling managers, superintendents, and engineers in the office, company drill site managers on rigs, and drilling contractor and service company personnel both on site and in the office all to understand the value of the technology, as well as know how to apply it.\u0000 The implementation process included an initial awareness phase of sharing successes by early adopters to create demand for the technology. Implementation included comprehensive training, management support, technical tools, and ongoing support.\u0000 The result of the initiative was a dramatic improvement in drilling performance. Significant increases in rates of penetration were achieved with virtually no added operational cost. Good results have been obtained in all business units, and the processes have evolved into routine practices.\u0000 The key conclusion is that proven marketing techniques can be adapted and applied to internal initiatives. The technology of marketing is effective and available, but adapting it to use internally is not trivial or obvious. On some previous initiatives, the approach was to deliver the technology, then create demand for it. The technique used this time was to create the demand first, then deliver the technology. This approach was successful in reducing opposition.\u0000 Early adopters must be identified and supported. Their initial successes are used to create demand for the technology and willingness to participate in training and learning. Training must be delivered to all of the people involved to enable application of the new process or technology.\u0000 Management support and technical support are both essential to get past difficulties. Patience and understanding are the best techniques to deal with resistance. Ultimately, successful results are the key to full adoption, but successful results cannot be achieved without the previous steps.\u0000 This case history includes both the principles and the application to a real case, with enough information on the drilling technology to understand the marketing process. The novel and additive information is how to adapt marketing technology for internal use, which is important for companies to adopt new technology faster.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"4 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":"133994556","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":"Natural Gamma Ray Tool Response Discrepancies: Not Always Due to the Calibration!","authors":"F. Allioli, L. Nicoletti, C. Stoller, Libai Xu","doi":"10.2118/191669-MS","DOIUrl":"https://doi.org/10.2118/191669-MS","url":null,"abstract":"It is not uncommon to note discrepancies in natural gamma ray (NGR) data from different designs of gamma ray (GR) tools run in the same well. These discrepancies are often blamed on inaccurate primary or secondary calibrations of the tools; however, it can be shown that in many cases, the different readings are inherent in the NGR measurement itself. Because the primary calibration is performed at the University of Houston (UH) in a reference formation with a specific mixture of thorium, uranium, and potassium, a change in the relative elemental concentrations results in a change of the energy spectrum of the gamma rays that reach the tool’s detector. The tool response to the different energies depends on a large number of factors; e.g., thickness and type of material traversed by the gamma rays, dimensions and type of the GR detector, as well as differences in threshold settings of the acquisition electronics. The standard environmental corrections for NGR tools correct for borehole effects (mud weight and composition, borehole size, and tool position in the borehole), so that the tool response to a given formation is independent of the borehole environment.\u0000 In this paper, we present a detailed Monte-Carlo modeling study quantifying the impact of the tool and detector design on the sensitivity to the three predominant naturally occurring radioactive materials (Th, U, and K). Also, the modeling study includes the impact the thickness and type of the materials have that is traversed by the gamma rays before reaching the detector. The modeling is benchmarked against the measured response in formations with a known Th, U, and K concentration, such as the UH Th and U pits, or internal calibration facilities.\u0000 The modeling results show that there can be significant discrepancies in the response of different tools to the same formation if the relative Th, U, and K concentrations deviate considerably from those in the UH reference pit. This condition will be illustrated by field cases with comparisons of the total NGR measurement and the spectral NGR measurement, which show that tool-to-tool differences can be attributed to a change of the composite energy spectrum of the emitters from the formation.\u0000 Finally, it can be shown that the tool calibration, as well as the interpretation of tool discrepancies, can be improved by using not only a 200-gAPI reference but also an independent Th, U, and K calibration associated with specific response functions for each tool design.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"13 23","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2018-09-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133086526","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":"Contribution of Oil and Gas Production in The US to The Climate Change","authors":"Olivier Lançon, B. Hascakir","doi":"10.2118/191482-MS","DOIUrl":"https://doi.org/10.2118/191482-MS","url":null,"abstract":"\u0000 The oil and gas industry has often been blamed for its major contribution to greenhouse gas releases and designated as a target to knock down by media, activists, and environmentalists. It is true to say that without Oil and Gas Industry, anthropogenic emissions of CO2 and CH4 would be much lower. Similarly, it is also true to state that without this industry and petroleum products, our life standards would be much different than the current standards. One should not confuse an activity which generates greenhouse gases, and the effect of product consumption. Evaluating the real routine emissions of the oil and gas industry on the same mode than every other industry is possible and constitutes the objective of this work. As a preliminary result, however, data coming from the Environmental Protection Agency (EPA) clearly highlight that oil and gas production accounts for at least less than 10% of the greenhouse gas emissions from the energy sector in the United States. To more precisely evaluate these emissions, this study relied on environmental impact reports in terms of greenhouse gas emissions, which are available for every production site in the U.S, as well as the oil and gas consumption in the US over the year 2015. Emissions happen during three different stages of the hydrocarbon production; extraction, flaring and venting, and fugitive emissions. The importance of each stage in terms of emissions is extremely variable, depending on the quality of the oil, the field location, and the existence of an outlet for the produced gas. The greenhouse gas emissions contribution from the Oil and Gas industry is 3% for extraction, and about 0% for flaring and venting, and 0% of fugitive emissions in the US. The remaining U.S greenhouse gas emissions while processing petroleum products are due to refining at 88%, and transportation at 9%. However, these results are extremely different for Canadian oil sands, Venezuela heavy oil, Arabian light oil, or Indonesian gas condensate. Worldwide, greenhouse emission source for petroleum industry are 10% for extraction, 19% for flaring and venting, 6% of fugitive emissions, 4% of transport, and 61% of the refinery. As a result, 3.5% of greenhouse gases emitted while processing petroleum products are due to Oil and Gas industry. Based on these results, an extrapolation to the worldwide Oil and Gas production enable to assess the participation of this industry to total emissions. Results show that less than 3 % of worldwide greenhouse emissions comes actually from Oil and Gas industry.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"23 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":"132252957","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":"Lunar Drilling – Challenges and Opportunities","authors":"S. Sawaryn, P. Bustin, M. Cain, I. Crawford, Sungwoo Lim, Alexander R. Linossier, D. Smith","doi":"10.2118/191624-MS","DOIUrl":"https://doi.org/10.2118/191624-MS","url":null,"abstract":"\u0000 Plans are being developed to drill and core a 100m deep hole on the Moon, an ambitious step beyond the 2.986m depth achieved at the Apollo 17 landing site in 1972. There are many scientific reasons for doing this, including determining the lunar geology and mineralogy below the meteorite-shattered regolith surface and its volatile content and heat flow, and identifying resources for future human space exploration. The complexities are such that the mission lead time is 15 plus years.\u0000 Drilling in the lunar environment poses many different technical challenges compared with terrestrial activity, although there are parallels, starting with the geological prognosis, similar to an oilfield exploration play. Operationally, the drilling equipment must escape Earth's gravitational pull. It must then travel almost 400,000 km to the drill site before it can be deployed and drilling starts. With each Kilogram of payload currently costing over $1.2 Million (Astrobotic Payload User Guide) this limits the available continuous power to approximately 100W, a minute fraction of its terrestrial counterparts. At these distances a radio signal takes 2.5 seconds to make the round trip, so the deployment and subsequent drilling activities must be largely autonomous. To add to the difficulties, the Moon's gravitational pull is only one sixth that of the Earth and it has no atmosphere, introducing weight on bit and hole cleaning problems. Despite the low gravity, displaced solids can still fall and obstruct the hole and some form of casing will be needed to secure the hole as it is drilled. The associated weight, power and geometrical limitations make this another serious technical challenge that must be overcome. With little or no chance to intervene, the operation must aim to be engineered to be right-first-time.\u0000 In the last decade, automation in oil and gas drilling has advanced considerably (Veila 2016; Hseih 2017). The number of autonomous activities has expanded and system reliability has improved. This, and other aspects of oil and gas experience, coupled with space exploration expertise and technology will be combined to make this happen. The pay-back for the oil and gas industry's involvement in this endeavor will be a step change in reliability and efficiency that results from satisfying the demanding conditions and clinical attention to detail that will be necessary to succeed.\u0000 The paper contains details of the goals, challenges and current thinking that drilling on the Moon entails, and the parallels with oil and gas drilling. This comes at a time when there is a renewed interest in further exploration of our solar system, particularly the Moon and Mars.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"11 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":"133123161","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":"Bringing the Sucker Rod Pumping Unit into the Classroom with the Use of the Internet of Things","authors":"C. Teodoriu, Erik Pienknagura","doi":"10.2118/191552-MS","DOIUrl":"https://doi.org/10.2118/191552-MS","url":null,"abstract":"\u0000 Artificial lift and particularly sucker rod pumping units are the most applied technologies for oil wells. While the equipment as such requires strong mechanical background, the use of the equipment remains solely the responsibility of petroleum engineers. Teaching them the working principles and functions of the equipment could be a challenging process when using only classroom related tools such as multimedia, short pieces of equipment, etc. As a response to this shortcoming, a new laboratory has been developed at the University of Oklahoma, which includes a large-scale pumping unit that is capable to be programed to simulate any situation in real time and use the Internet of Things to gather real time data and create tailored diagnostic tools that students and laboratory staff can utilize for many applications.\u0000 This paper focuses on the need to add a hands-on teaching experience to the classroom, and what type of data can be mined and used to accomplish specific objectives. It is required for our future petroleum engineers that they know how to apply basic industry principles and increase problem solving skills involving machinery. The proposed laboratory would be capable to deliver all standard monitored parameters of a sucker rod pumping unit to any classroom through a networked connection and allow the students to make decisions or experiment in real time with the setup. By being a large-scale setup, students can easily observe how the unit works, visualize downhole pumping operations, identify where the sensors are placed, and learn how to use raw data for any intended purpose. In other words, the entire artificial lifting process can be seen and operated from any classroom on campus remotely, and advanced analysis can be performed by the students or staff.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"22 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":"132170211","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":"Novel Analyses and Design of Relief Wells Considering 3D Effects","authors":"E. Sweeney, Lei Zhou, G. Cunha, J. H. Knight","doi":"10.2118/191518-MS","DOIUrl":"https://doi.org/10.2118/191518-MS","url":null,"abstract":"\u0000 In developing a relief well contingency, current industry standard practice is to use a one-dimensional (1D) multiphase flow model to determine the requirements such as pump rate and mud weight to kill the blowout well. However, this does not consider certain variables. For instance, this analysis returns the same results regardless of the intercept angle of the relief well (i.e. results are identical if the relief well intercepts at a steep angle into the direction of flow, or if it intercepts at a steep angle in the same direction of flow).\u0000 A novel approach has been developed that considers the three-dimensional vector effects when a blowing out well is killed by means of a relief well intercept. This analysis offers safety and environmental benefits for well kill design and operations because it provides results which more accurately reflect the physical principles. This allows for optimization of a relief well design. For instance, this more comprehensive analysis allows the possibility to design a relief well with shallower intercept depth and lower pump requirements with the potential for an earlier kill.\u0000 This new method considers the complex interaction of the countercurrent flow that occurs at the relief well intercept and can utilize computational fluid dynamics (CFD). This enables optimization of parameters previously not considered such as specific spray design from the relief well. For instance, industry currently assumes that there is an advantage to pumping the kill fluid down the annulus of the relief well. The frictional losses are lowered (compared to pumping down the drillstring), thereby minimizng the pump requirements and maximizing the achievable rate for given pump capability. Whilst this may indeed be the case, the research covered in this paper shows that, depending on the circumstances, there can be a benefit to designing the spray pattern from the flow from the relief well at the intercept.\u0000 Various relief well kill cases were analyzed by both the standard method and the new method and the results compared. The new method predicted that relief well kills could be made with lower rates and pressures than predicted by the standard model. Using the new method offers an opportunity to increase the accuracy of relief well planning, enabling a more precise understanding of what may be achievable.\u0000 A test apparatus was designed and created to verify which of the two methods was more accurate. Physical experiments indicate that results from the proposed method match the test results closer than the standard approach.","PeriodicalId":441169,"journal":{"name":"Day 3 Wed, September 26, 2018","volume":"20 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":"128080817","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}