Kazakhstan has set a lofty goal of becoming one of the world's top 30 developed countries by 2050. This can be accomplished by growing up well-versed, competent, and forward-thinking human capital. We previously discussed curriculum, courses, internships, and student development as part of the World Economic Forum (WEF) pilot project supported by Chevron, Eni, and Shell (Sponsors) to strengthen oil and gas human capital in Kazakhstan (SPE-195903 and SPE-201272). During regular visits, the WEF sponsors and Colorado School of Mines (Mines) could assess the Satbayev University (SU) PE department and underlined the importance of faculty growth. Academic workshops on topics such as course and syllabus design, student assessment, and ABET accreditation standards have been held both offline and online. Meanwhile, to advance the PE program, faculty research capacity must be globally competitive. To begin, the Kazakhstani government distributed visiting scholarship awards on behalf of the supporting World Bank in 2018. Shell Kazakhstan took the initiative and co-funded two PhD candidates so they could perform their research experiments at Pennsylvania State University (PennState). In addition, Mines has gone above and beyond the WEF scope by offering two fully-funded PhD scholarships to exceptional SU faculty. Through the newly constituted Industry-Advisory Board (IAB), the WEF Sponsors emphasized strong contact with the industry, which assisted in identifying a few research topics. These discussions resulted in formulation of four research proposals that were submitted to the Ministry of Education and Science Grants in 2020 and are being co-funded by Sponsors. This collaboration has yielded the approval of two projects by the State. Finally, under the auspices of the IAB meetings, the PE department has been offered opportunity to collaborate with the national KazMunayGas on the company-related project. While academic cooperation is well-known, research and its outcomes are even more critical in today's fast-changing environment. Universities must quickly adapt to industry best practices while remaining committed to their global mission of contributing to national growth and human potential. This paper discusses effective approaches for industry-academia collaboration.
{"title":"Improving the Local Research Capacity through the Industry-Academia Collaboration in Kazakhstan","authors":"Murat Syzdykov, Zhassulan Dairov, J. Miskimins","doi":"10.2118/205977-ms","DOIUrl":"https://doi.org/10.2118/205977-ms","url":null,"abstract":"\u0000 Kazakhstan has set a lofty goal of becoming one of the world's top 30 developed countries by 2050. This can be accomplished by growing up well-versed, competent, and forward-thinking human capital. We previously discussed curriculum, courses, internships, and student development as part of the World Economic Forum (WEF) pilot project supported by Chevron, Eni, and Shell (Sponsors) to strengthen oil and gas human capital in Kazakhstan (SPE-195903 and SPE-201272). During regular visits, the WEF sponsors and Colorado School of Mines (Mines) could assess the Satbayev University (SU) PE department and underlined the importance of faculty growth. Academic workshops on topics such as course and syllabus design, student assessment, and ABET accreditation standards have been held both offline and online. Meanwhile, to advance the PE program, faculty research capacity must be globally competitive.\u0000 To begin, the Kazakhstani government distributed visiting scholarship awards on behalf of the supporting World Bank in 2018. Shell Kazakhstan took the initiative and co-funded two PhD candidates so they could perform their research experiments at Pennsylvania State University (PennState). In addition, Mines has gone above and beyond the WEF scope by offering two fully-funded PhD scholarships to exceptional SU faculty. Through the newly constituted Industry-Advisory Board (IAB), the WEF Sponsors emphasized strong contact with the industry, which assisted in identifying a few research topics. These discussions resulted in formulation of four research proposals that were submitted to the Ministry of Education and Science Grants in 2020 and are being co-funded by Sponsors. This collaboration has yielded the approval of two projects by the State. Finally, under the auspices of the IAB meetings, the PE department has been offered opportunity to collaborate with the national KazMunayGas on the company-related project.\u0000 While academic cooperation is well-known, research and its outcomes are even more critical in today's fast-changing environment. Universities must quickly adapt to industry best practices while remaining committed to their global mission of contributing to national growth and human potential. This paper discusses effective approaches for industry-academia collaboration.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76029257","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}
In the past decades, financial institutions have led the way for companies to adhere to international standards for social performance. The journey began in the Industrial Revolution, when negative societal business impacts rapidly escalated, which led people to demand for their management. Initially focused on working conditions, impacts on the environment soon started to gain notice. Halfway through the 20th century, a combination of oil spills and mass media attention generated enough public pressure for the United States to sign the first piece of legislation requiring the environmental impact assessment. With this law and its replication abroad, however, came the concern with social impacts as well. Both environmental and social performance expectations soon spread internationally and, by the 1980s, multilateral financial institutions, most prominently the World Bank, incorporated such considerations into their investment and lending practices, which is the source of all such international standards today. These standards require the establishment of a social management system to integrate risk and impact management processes and stakeholder engagement activities. Given the challenge of implementing these requirements, a social risk management development framework is proposed to bring together the extensive and multidisciplinary demands of effective social performance. Five development areas are proposed: governance, social policy, tools, resourcing and capacity, and knowledge sharing. This is an important step to take today as it is expected that the next decades will see these international demands increase, possibly by ever increasing governmental regulation.
{"title":"Social Risk Management as a Response to Increasing International Pressure for Social Performance","authors":"J. D. Borbor, K. Cranenburgh, C. Luca","doi":"10.2118/206240-ms","DOIUrl":"https://doi.org/10.2118/206240-ms","url":null,"abstract":"\u0000 In the past decades, financial institutions have led the way for companies to adhere to international standards for social performance. The journey began in the Industrial Revolution, when negative societal business impacts rapidly escalated, which led people to demand for their management. Initially focused on working conditions, impacts on the environment soon started to gain notice. Halfway through the 20th century, a combination of oil spills and mass media attention generated enough public pressure for the United States to sign the first piece of legislation requiring the environmental impact assessment. With this law and its replication abroad, however, came the concern with social impacts as well. Both environmental and social performance expectations soon spread internationally and, by the 1980s, multilateral financial institutions, most prominently the World Bank, incorporated such considerations into their investment and lending practices, which is the source of all such international standards today. These standards require the establishment of a social management system to integrate risk and impact management processes and stakeholder engagement activities. Given the challenge of implementing these requirements, a social risk management development framework is proposed to bring together the extensive and multidisciplinary demands of effective social performance. Five development areas are proposed: governance, social policy, tools, resourcing and capacity, and knowledge sharing. This is an important step to take today as it is expected that the next decades will see these international demands increase, possibly by ever increasing governmental regulation.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87800592","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}
In May 2019, the merger between Wintershall GmbH and DEA Deutsche Erdoel AG was closed, which was the start of Wintershall Dea.This paper provides detailed insight into managing reserves and resource information during this merger. After merger, three resource management activities required attention: (i) combining existing resources reporting, (ii) defining a lean but effective resources management and control system, and (iii) ensuring readiness for Initial Public Offering (IPO) by establishing an external independent evaluation of resources ("external resource audit"). This paper describes objectives, challenges and solutions on reserves and resources reporting of the new company. The merged reserves and resources database of the previous year's reports had to consider audits from two different reporting systems in parallel to four different external auditors.With priorities defined by status of external auditing, operatorship and asset share a common database was derived and could immediately be used for financial transactions such as the issuance of an inaugural bond. The new system for internal reporting of petroleum resources provides a fit-for-purpose approach, such as a consistent interpretation of commerciality criteria or definition of resources sub-classes.Particular attention was paid to synergies with respect to business planning, strategic portfolio analysis, and a link to technology & innovation. By defining specific attributes and sub-processes, the portfolio can be analyzed systematically. This provides additional insights and ensures synergies with business planning, strategic planning as well as internal technology initiatives. A systematic resource control system is defined focusing on internal review, external and internal audits as well as synergetic use of project reviews. Moreover, a feedback loop for continuous improvement of reservoir management allows attending to important audit observations. The external resource audit to ensure IPO readiness was structured to assign tasks for head office, business units and auditing company.The sequence of events from introduction to assets to reconciliation of differences between auditor and company was set-up, executed and monitored.Focus was on the definition of a structured but agile approach for external independent evaluation of all reserves and contingent resources.
2019年5月，Wintershall GmbH和DEA Deutsche Erdoel AG的合并完成，这是Wintershall DEA的开始。本文提供了详细的见解，管理储备和资源信息，在此合并。合并后，需要注意三项资源管理活动:(i)合并现有资源报告，(ii)定义精简但有效的资源管理和控制系统，以及(iii)通过建立外部独立的资源评估(“外部资源审计”)确保首次公开发行(IPO)的准备工作。本文描述了新公司储量和资源报告的目标、挑战和解决方案。前一年报告的合并储备和资源数据库必须同时考虑来自两个不同报告系统和四个不同外聘审计员的审计。根据外部审计、经营和资产分享的状况确定优先次序后，建立了一个共同数据库，可立即用于诸如发行首期债券等金融交易。石油资源内部报告的新制度提供了一种适合目的的办法，例如对商业标准或资源子类定义的一致解释。特别注意在业务规划、战略组合分析以及与技术和创新的联系方面的协同作用。通过定义特定的属性和子过程，可以系统地分析项目组合。这提供了额外的见解，并确保与业务规划，战略规划以及内部技术计划的协同作用。确定了一个系统的资源控制系统，重点是内部审查、外部和内部审计以及协同利用项目审查。此外，水库管理的持续改进的反馈循环允许出席重要的审计意见。外部资源审计以确保IPO准备就绪，并为总部、业务部门和审计公司分配任务。从引入资产到调整审计师和公司之间的差异，一系列事件被建立、执行和监控。重点是确定一种结构化但灵活的方法，以便对所有储量和临时资源进行外部独立评价。
{"title":"Business-Oriented Reserves and Resource Management - Experiences from a Merger","authors":"T. Dose, Gunar Kachel","doi":"10.2118/206322-ms","DOIUrl":"https://doi.org/10.2118/206322-ms","url":null,"abstract":"\u0000 In May 2019, the merger between Wintershall GmbH and DEA Deutsche Erdoel AG was closed, which was the start of Wintershall Dea.This paper provides detailed insight into managing reserves and resource information during this merger.\u0000 After merger, three resource management activities required attention: (i) combining existing resources reporting, (ii) defining a lean but effective resources management and control system, and (iii) ensuring readiness for Initial Public Offering (IPO) by establishing an external independent evaluation of resources (\"external resource audit\"). This paper describes objectives, challenges and solutions on reserves and resources reporting of the new company.\u0000 The merged reserves and resources database of the previous year's reports had to consider audits from two different reporting systems in parallel to four different external auditors.With priorities defined by status of external auditing, operatorship and asset share a common database was derived and could immediately be used for financial transactions such as the issuance of an inaugural bond.\u0000 The new system for internal reporting of petroleum resources provides a fit-for-purpose approach, such as a consistent interpretation of commerciality criteria or definition of resources sub-classes.Particular attention was paid to synergies with respect to business planning, strategic portfolio analysis, and a link to technology & innovation. By defining specific attributes and sub-processes, the portfolio can be analyzed systematically. This provides additional insights and ensures synergies with business planning, strategic planning as well as internal technology initiatives.\u0000 A systematic resource control system is defined focusing on internal review, external and internal audits as well as synergetic use of project reviews. Moreover, a feedback loop for continuous improvement of reservoir management allows attending to important audit observations.\u0000 The external resource audit to ensure IPO readiness was structured to assign tasks for head office, business units and auditing company.The sequence of events from introduction to assets to reconciliation of differences between auditor and company was set-up, executed and monitored.Focus was on the definition of a structured but agile approach for external independent evaluation of all reserves and contingent resources.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90498704","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}
Rafael M. D. Rosa, Arthur B. Soprana, V. Girardi, Fernando M. Villagra
This work presents a numerical assessment of chemical inhibitor injection to mitigate wax deposition in unconventional wells. The goal of this study is to simulate the deposition of wax under several operational conditions and later optimize the chemical inhibitor injection position, using two different types of numerical simulations. A transient one-dimensional multiphase flow simulator - ALFAsim, with a dedicated wax model, was used to predict flow conditions such pressure, temperature, holdup and flow pattern profiles, as well the position and rates that wax accumulates. The results from the 1D simulation were then used as boundary conditions in a 3D CFD simulator, which aimed to assess how long it would take to a satisfactory homogenization of the inhibitor with the flow and what would be the minimum depth for the injector should be installed. In this work, a 1D multiphase flow simulator with wax deposition model was used to identify on which operational conditions (flow rates and environmental temperatures) an unconventional well would start to present wax deposition on its tubing walls. After defining the susceptible region where the paraffin could deposit, it was important to verify if the inhibitor would be well homogenized with the stream when reaching this region. For that, a 3D CFD simulation was performed, using information obtained directly from the 1D simulator as boundary conditions. The CFD model was capable to show the mixing evolution of the inhibitor with the stream and it was possible to determine the minimum distance where the injector should be placed to guarantee such homogeneity. A real well was selected to provide comparisons between field observations and simulated data, in order to validate the model assumptions and accuracy.
{"title":"Assessment of Chemical Injection to Mitigate Wax Deposition in Unconventional Wells","authors":"Rafael M. D. Rosa, Arthur B. Soprana, V. Girardi, Fernando M. Villagra","doi":"10.2118/206206-ms","DOIUrl":"https://doi.org/10.2118/206206-ms","url":null,"abstract":"\u0000 This work presents a numerical assessment of chemical inhibitor injection to mitigate wax deposition in unconventional wells. The goal of this study is to simulate the deposition of wax under several operational conditions and later optimize the chemical inhibitor injection position, using two different types of numerical simulations. A transient one-dimensional multiphase flow simulator - ALFAsim, with a dedicated wax model, was used to predict flow conditions such pressure, temperature, holdup and flow pattern profiles, as well the position and rates that wax accumulates. The results from the 1D simulation were then used as boundary conditions in a 3D CFD simulator, which aimed to assess how long it would take to a satisfactory homogenization of the inhibitor with the flow and what would be the minimum depth for the injector should be installed.\u0000 In this work, a 1D multiphase flow simulator with wax deposition model was used to identify on which operational conditions (flow rates and environmental temperatures) an unconventional well would start to present wax deposition on its tubing walls. After defining the susceptible region where the paraffin could deposit, it was important to verify if the inhibitor would be well homogenized with the stream when reaching this region. For that, a 3D CFD simulation was performed, using information obtained directly from the 1D simulator as boundary conditions. The CFD model was capable to show the mixing evolution of the inhibitor with the stream and it was possible to determine the minimum distance where the injector should be placed to guarantee such homogeneity. A real well was selected to provide comparisons between field observations and simulated data, in order to validate the model assumptions and accuracy.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90534481","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}
Rubén Dario Gutiérrez Bedoya, C. Fonseca, Michelle Alba Naranjo Leon
As most oilfields in Ecuador are approaching to the end of the service contracts under an advanced degree of maturity, it was imperative to implement a fast-track integrated methodology that supports the decisionmaking process during assets' evaluation. This practice aimed to identify new business opportunities and assure the rehabilitation of brownfields. These fields became a target for investors willing to intervene in new joint ventures with moderate risk to boost production and returns. The methodology is prepared to overcome specific challenges such as severe reservoir pressure depletion, harsh water management issues, facilities constraints and integrity. All this while keeping economics and safe operational standards. This process is divided into five stages: First, the diagnosis of field challenges and associated risks, so that review the current status of subsurface and surface aspects. Then, the following three parallel phases are focused on the study of reservoir architecture, dynamics and performance. Finally, the remaining potential of the asset is assessed by integrating action plans to take advantage of current facilities capacities. This workflow was implemented for the evaluation of three assets: Asset 1: Mature field with a secondary gas cap where its current reservoir pressure is 800 psia (initial pressure 4,200 psia). The asset was evaluated in fifteen (15) days resulting in an integrated solution with 14 activities: conversions to injectors, water source, upsizing, reactivations, change zone, and new wells. The results presented an incremental recovery factor of 6% (by 2028) with an expected production peak of 3,500 BOPD (by 2021). Asset 2: A field producing from two main reservoirs with harsh water management issues under a non-monitored waterflooding scheme with challenging sweet spots identification was evaluated in 10 days, resulting in a redevelopment plan considering: production losses optimization, sixteen (16) activities: workovers, dual completions, new wells, reentry, shut-in, and conversion to water injectors. This evaluation delivered an incremental recovery factor of 10% (by 2029). Asset 3: Producing for around one-hundred (100) years with 3,000 wells drilled. There was a lack of pressure support and facilities and well completions integrity. The fast-track assessment focused on production optimization lasted fifteen (15) days, resulting in one-hundred eighteen (118) wells for reactivation representing an additional recovery factor of 3% (by 2029). This work supported the process for contract's renegotiation and assets' acquisition. This integrated methodology aimed to maximize the assets' value while considering the involved shareholders' needs. Each asset was analysed in an integrated and collaborative manner through the propper resources identification and the usage of the latest technology and workflows. High-resolution reservoir simulation, complex python scripts, and a chemical processes simu
{"title":"Solid Fast-Track Evaluation Methodology: Supporting the Decision-Making Process in the Development of Mature Assets","authors":"Rubén Dario Gutiérrez Bedoya, C. Fonseca, Michelle Alba Naranjo Leon","doi":"10.2118/206378-ms","DOIUrl":"https://doi.org/10.2118/206378-ms","url":null,"abstract":"\u0000 As most oilfields in Ecuador are approaching to the end of the service contracts under an advanced degree of maturity, it was imperative to implement a fast-track integrated methodology that supports the decisionmaking process during assets' evaluation. This practice aimed to identify new business opportunities and assure the rehabilitation of brownfields. These fields became a target for investors willing to intervene in new joint ventures with moderate risk to boost production and returns.\u0000 The methodology is prepared to overcome specific challenges such as severe reservoir pressure depletion, harsh water management issues, facilities constraints and integrity. All this while keeping economics and safe operational standards.\u0000 This process is divided into five stages: First, the diagnosis of field challenges and associated risks, so that review the current status of subsurface and surface aspects. Then, the following three parallel phases are focused on the study of reservoir architecture, dynamics and performance. Finally, the remaining potential of the asset is assessed by integrating action plans to take advantage of current facilities capacities.\u0000 This workflow was implemented for the evaluation of three assets:\u0000 Asset 1:\u0000 Mature field with a secondary gas cap where its current reservoir pressure is 800 psia (initial pressure 4,200 psia). The asset was evaluated in fifteen (15) days resulting in an integrated solution with 14 activities: conversions to injectors, water source, upsizing, reactivations, change zone, and new wells. The results presented an incremental recovery factor of 6% (by 2028) with an expected production peak of 3,500 BOPD (by 2021).\u0000 Asset 2:\u0000 A field producing from two main reservoirs with harsh water management issues under a non-monitored waterflooding scheme with challenging sweet spots identification was evaluated in 10 days, resulting in a redevelopment plan considering: production losses optimization, sixteen (16) activities: workovers, dual completions, new wells, reentry, shut-in, and conversion to water injectors. This evaluation delivered an incremental recovery factor of 10% (by 2029).\u0000 Asset 3:\u0000 Producing for around one-hundred (100) years with 3,000 wells drilled. There was a lack of pressure support and facilities and well completions integrity. The fast-track assessment focused on production optimization lasted fifteen (15) days, resulting in one-hundred eighteen (118) wells for reactivation representing an additional recovery factor of 3% (by 2029).\u0000 This work supported the process for contract's renegotiation and assets' acquisition. This integrated methodology aimed to maximize the assets' value while considering the involved shareholders' needs.\u0000 Each asset was analysed in an integrated and collaborative manner through the propper resources identification and the usage of the latest technology and workflows.\u0000 High-resolution reservoir simulation, complex python scripts, and a chemical processes simu","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89589745","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}
Tsubasa Onishi, Hongquan Chen, A. Datta-Gupta, Srikanta Mishra
We present a novel deep learning-based workflow incorporating a reduced physics model that can efficiently visualize well drainage volume and pressure front propagation in unconventional reservoirs in near real-time. The visualizations can be readily used for qualitative and quantitative characterization and forecasting of unconventional reservoirs. Our aim is to develop an efficient workflow that allows us to ‘see’ within the subsurface given measured data, such as production data. The most simplistic way to achieve the goal will be to merely train a deep learning-based regression model where the input consists of some measured data, and the output is a subsurface image, such as pressure field. However, the high output dimension that corresponds to spatio-temporal steps makes the training inefficient. To address this challenge, an autoencoder network is applied to discover lower dimensional latent variables that represent high dimensional output images. In our approach, the regression model is trained to predict latent variables, instead of directly constructing an image. In the prediction step, the trained regression model first predicts latent variables given measured data, then the latent variables will be used as inputs of the trained decoder to generate a subsurface image. In addition, fast marching-method (FMM)-based rapid simulation workflow which transforms original 2D or 3D problems into 1D problems is used in place of full-physics simulation to efficiently generate datasets for training. The capability of the FMM-based rapid simulation allows us to generate sufficient datasets within realistic simulation times, even for field scale applications. We first demonstrate the proposed approach using a simple illustrative example. Next, the approach is applied to a field scale reservoir model built after the publicly available data on the Hydraulic Fracturing Test Site-I (HFTS-I), which is sufficiently complex to demonstrate the power and efficacy of the approach. We will further demonstrate the utility of the approach to account for subsurface uncertainty. Our approach, for the first time, allows data-driven visualization of unconventional well drainage volume in 3D. The novelty of our approach is the framework which combines the strengths of deep learning-based models and the FMM-based rapid simulation. The workflow has flexibility to incorporate various spatial and temporal data types.
{"title":"An Efficient Deep Learning-Based Workflow Incorporating a Reduced Physics Model for Subsurface Imaging in Unconventional Reservoirs","authors":"Tsubasa Onishi, Hongquan Chen, A. Datta-Gupta, Srikanta Mishra","doi":"10.2118/206065-ms","DOIUrl":"https://doi.org/10.2118/206065-ms","url":null,"abstract":"\u0000 We present a novel deep learning-based workflow incorporating a reduced physics model that can efficiently visualize well drainage volume and pressure front propagation in unconventional reservoirs in near real-time. The visualizations can be readily used for qualitative and quantitative characterization and forecasting of unconventional reservoirs.\u0000 Our aim is to develop an efficient workflow that allows us to ‘see’ within the subsurface given measured data, such as production data. The most simplistic way to achieve the goal will be to merely train a deep learning-based regression model where the input consists of some measured data, and the output is a subsurface image, such as pressure field. However, the high output dimension that corresponds to spatio-temporal steps makes the training inefficient. To address this challenge, an autoencoder network is applied to discover lower dimensional latent variables that represent high dimensional output images. In our approach, the regression model is trained to predict latent variables, instead of directly constructing an image. In the prediction step, the trained regression model first predicts latent variables given measured data, then the latent variables will be used as inputs of the trained decoder to generate a subsurface image. In addition, fast marching-method (FMM)-based rapid simulation workflow which transforms original 2D or 3D problems into 1D problems is used in place of full-physics simulation to efficiently generate datasets for training. The capability of the FMM-based rapid simulation allows us to generate sufficient datasets within realistic simulation times, even for field scale applications.\u0000 We first demonstrate the proposed approach using a simple illustrative example. Next, the approach is applied to a field scale reservoir model built after the publicly available data on the Hydraulic Fracturing Test Site-I (HFTS-I), which is sufficiently complex to demonstrate the power and efficacy of the approach. We will further demonstrate the utility of the approach to account for subsurface uncertainty. Our approach, for the first time, allows data-driven visualization of unconventional well drainage volume in 3D. The novelty of our approach is the framework which combines the strengths of deep learning-based models and the FMM-based rapid simulation. The workflow has flexibility to incorporate various spatial and temporal data types.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88594695","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}
The oilfield is in many ways the backbone of the world economy. Historically economic recessions and booms were linked directly or indirectly to the oil price, itself governed by supply and demand. Since the start of this industry, it has experienced multiple scandals and major accidents that have affected its path to date. In 2001 the Enron scandal of poor accounting practices shook the entire stock market, and it contributed to the complete recession in the same year. Not too long after, a supermajor revealed in 2004 a reserves accounting error that surprised the world. In 2010 the Deepwater Horizon blow out known as the "Macondo Incident" caused serious damage to the environment and significant fines to be paid in compensation due to poor engineering practice. Incidents like these arise concurrent with times of high demand and are instructive as we study their causes and effects on the oil industry and therefore the global economy. Areas of study for this paper include reserves/production estimation as well as ethical considerations for the oil industry at large. Our study is based on the review of uncertainty in both the subsurface and surface parts of oil and gas production. We refer to the previous classifications of uncertainty for the subsurface part and focus on the uncertainty currently existing within the surface production system. Current surface production monitoring methods are discussed. We propose a more automated process to reduce the current uncertainty about hydrocarbon production. Artificial intelligence applicability in the surface production system is investigated. Additionally, in this paper we review the previously mentioned poor practices and accidents briefly and use them to guide our suggestions about preventive actions to avoid future wrongdoing and incidents. We attempt to provide an objective for oilfield ethics and advocate for a unified oilfield industry code of ethics. However due to the large diversity that exists in the wide range of oilfield disciplines, a single code of ethics may not be applicable. Accordingly, we propose a guideline that may be used by different parts of the oilfield industry to develop an application-specific code of ethics. It is hoped that this guideline will guard against the gaps that may foster errors that affect the oilfield industry and global markets.
{"title":"The Fall and Rise of Oilfield Ethics","authors":"A. Dahroug, K. O'Connell","doi":"10.2118/206176-ms","DOIUrl":"https://doi.org/10.2118/206176-ms","url":null,"abstract":"\u0000 The oilfield is in many ways the backbone of the world economy. Historically economic recessions and booms were linked directly or indirectly to the oil price, itself governed by supply and demand. Since the start of this industry, it has experienced multiple scandals and major accidents that have affected its path to date.\u0000 In 2001 the Enron scandal of poor accounting practices shook the entire stock market, and it contributed to the complete recession in the same year. Not too long after, a supermajor revealed in 2004 a reserves accounting error that surprised the world. In 2010 the Deepwater Horizon blow out known as the \"Macondo Incident\" caused serious damage to the environment and significant fines to be paid in compensation due to poor engineering practice.\u0000 Incidents like these arise concurrent with times of high demand and are instructive as we study their causes and effects on the oil industry and therefore the global economy.\u0000 Areas of study for this paper include reserves/production estimation as well as ethical considerations for the oil industry at large.\u0000 Our study is based on the review of uncertainty in both the subsurface and surface parts of oil and gas production. We refer to the previous classifications of uncertainty for the subsurface part and focus on the uncertainty currently existing within the surface production system. Current surface production monitoring methods are discussed. We propose a more automated process to reduce the current uncertainty about hydrocarbon production. Artificial intelligence applicability in the surface production system is investigated.\u0000 Additionally, in this paper we review the previously mentioned poor practices and accidents briefly and use them to guide our suggestions about preventive actions to avoid future wrongdoing and incidents. We attempt to provide an objective for oilfield ethics and advocate for a unified oilfield industry code of ethics. However due to the large diversity that exists in the wide range of oilfield disciplines, a single code of ethics may not be applicable. Accordingly, we propose a guideline that may be used by different parts of the oilfield industry to develop an application-specific code of ethics. It is hoped that this guideline will guard against the gaps that may foster errors that affect the oilfield industry and global markets.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82718798","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}
Xiaoyang Xia, Eric T. Nelson, Daniel J Olds, L. Connor, He Zhang
In 2011, the Society of Petroleum Evaluation Engineers (SPEE) published Monograph 3 as an industry guideline for reserves evaluation of unconventionals, especially for probabilistic approaches. This paper illustrates the workflow recommended by Monograph 3. The authors also point out some dilemmas one may encounter when applying the guidelines. Finally, the authors suggest remedies to mitigate limitations and improve the utility of the approach. This case study includes about 300 producing shale wells in the Permian Basin. Referring to Monograph 3, analogous wells were identified based on location, geology, drilling-and-completion (D&C) technology; Technically Recoverable Resources (TRRs) of these analogous wells were then evaluated by Decline Curve Analysis (DCA). Next, five type-wells were developed with different statistical characteristics. Lastly, a number of drilling opportunities were identified and, consequently, a Monte Carlo simulation was conducted to develop a statistical distribution for undeveloped locations in each type-well area. The authors demonstrated the use of probit plots and demonstrated the binning strategy, which could best represent the study area. The authors tuned the binning strategy based on multiple yardsticks, including median values of normalized TRRs per lateral length, slopes of the distribution lines in lognormal plots, ratios of P10 over P90, and well counts in each type-well category in addition to other variables. The binning trials were based on different geographic areas, producing reservoirs, and operators, and included the relatively new concept of a "learning curve" introduced by the Society of Petroleum Engineers (SPE) 2018 Petroleum Resources Management System (PRMS). To the best of the authors’ knowledge, this paper represents the first published case study to factor in the "learning curves" method. This paper automated the illustrated workflow through coded database queries or manipulation, which resulted in high efficiencies for multiple trials on binning strategy. The demonstrated case study illustrates valid decision-making processes based on data analytics. The case study further identifies methods to eliminate bias, and present independent objective reserves evaluations. Most of the challenges and situations herein are not fully addressed in Monograph 3 and are not documented in the regulations of the U.S. Security and Exchange Commission (SEC) or in the PRMS guidelines. While there may be differing approaches, and some analysts may prefer alternate methods, the authors believe that the items presented herein will benefit many who are starting to incorporate Monograph 3 in their work process. The authors hope that this paper will encourage additional discussion in our industry.
{"title":"An Integrated Workflow for Reserves Evaluation in the U.S. Permian Basin Based on SPEE Monograph 3","authors":"Xiaoyang Xia, Eric T. Nelson, Daniel J Olds, L. Connor, He Zhang","doi":"10.2118/206362-ms","DOIUrl":"https://doi.org/10.2118/206362-ms","url":null,"abstract":"\u0000 In 2011, the Society of Petroleum Evaluation Engineers (SPEE) published Monograph 3 as an industry guideline for reserves evaluation of unconventionals, especially for probabilistic approaches. This paper illustrates the workflow recommended by Monograph 3. The authors also point out some dilemmas one may encounter when applying the guidelines. Finally, the authors suggest remedies to mitigate limitations and improve the utility of the approach.\u0000 This case study includes about 300 producing shale wells in the Permian Basin. Referring to Monograph 3, analogous wells were identified based on location, geology, drilling-and-completion (D&C) technology; Technically Recoverable Resources (TRRs) of these analogous wells were then evaluated by Decline Curve Analysis (DCA). Next, five type-wells were developed with different statistical characteristics. Lastly, a number of drilling opportunities were identified and, consequently, a Monte Carlo simulation was conducted to develop a statistical distribution for undeveloped locations in each type-well area.\u0000 The authors demonstrated the use of probit plots and demonstrated the binning strategy, which could best represent the study area. The authors tuned the binning strategy based on multiple yardsticks, including median values of normalized TRRs per lateral length, slopes of the distribution lines in lognormal plots, ratios of P10 over P90, and well counts in each type-well category in addition to other variables. The binning trials were based on different geographic areas, producing reservoirs, and operators, and included the relatively new concept of a \"learning curve\" introduced by the Society of Petroleum Engineers (SPE) 2018 Petroleum Resources Management System (PRMS). To the best of the authors’ knowledge, this paper represents the first published case study to factor in the \"learning curves\" method. This paper automated the illustrated workflow through coded database queries or manipulation, which resulted in high efficiencies for multiple trials on binning strategy. The demonstrated case study illustrates valid decision-making processes based on data analytics. The case study further identifies methods to eliminate bias, and present independent objective reserves evaluations. Most of the challenges and situations herein are not fully addressed in Monograph 3 and are not documented in the regulations of the U.S. Security and Exchange Commission (SEC) or in the PRMS guidelines. While there may be differing approaches, and some analysts may prefer alternate methods, the authors believe that the items presented herein will benefit many who are starting to incorporate Monograph 3 in their work process. The authors hope that this paper will encourage additional discussion in our industry.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84410431","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}
Defined by SPE as the application of basic and engineering sciences to the finding, development, and recovery of oil, gas and other resources from wells, petroleum engineering (PE) has been throughout the years falsely thought of as an amalgamation of other disciplines applied to the exploration and recovery of hydrocarbons. Integrating all PE subdisciplines in a manner efficient for teaching and learning is essential for securing the abundance of well-rounded market-attractive professionals. This paper discusses advantages individuals with PE background experience should exhibit in their employment in the oil and gas industry and academia. There is no point for students in going to school for a degree that will not hand them a competitive edge within their discipline. For graduate PEs, the job market is dependent on the quality of their respective academic programs and by extension to the quality of the teaching faculty. A steady oil and gas job market may not necessarily warrant robust employment opportunities, particularly straight after graduation. In a discipline like PE, where almost everything that matters takes place thousands of feet underground, apportioning credit for successes or responsibility for failures is itself a challenge. Decreases in student enrollments in PE programs reported by various universities during times of low oil and gas prices poses questions about the future of the PEs discipline, despite the steady demand for oil and gas in the world's energy mix. Academic programs interested in facilitating a smooth transition of their graduates into the industry should work in conjunction with practitioners to provide the correct balance between theory and practice in their coursework ensuring that once employment opportunities are created, they get filled with candidates of relevant education and training. PE degree-holding candidates should be the natural first choice for PE positions. This means that their educational and professional backgrounds should be providing them with an undisputed advantage which places them a leg above candidates from other disciplines. For instance, for a well completions job opening, there should not be a better alternative than a good PE specialized in well completions. If every PE graduate comes out of his or her program with a skillset which is superior to that of his or her competition, he or she will be the preferred choice for an oil and gas job.
{"title":"The True Market Value of a Good Petroleum Engineer: A Technical Perspective","authors":"A. Michael","doi":"10.2118/206272-ms","DOIUrl":"https://doi.org/10.2118/206272-ms","url":null,"abstract":"\u0000 Defined by SPE as the application of basic and engineering sciences to the finding, development, and recovery of oil, gas and other resources from wells, petroleum engineering (PE) has been throughout the years falsely thought of as an amalgamation of other disciplines applied to the exploration and recovery of hydrocarbons. Integrating all PE subdisciplines in a manner efficient for teaching and learning is essential for securing the abundance of well-rounded market-attractive professionals. This paper discusses advantages individuals with PE background experience should exhibit in their employment in the oil and gas industry and academia. There is no point for students in going to school for a degree that will not hand them a competitive edge within their discipline.\u0000 For graduate PEs, the job market is dependent on the quality of their respective academic programs and by extension to the quality of the teaching faculty. A steady oil and gas job market may not necessarily warrant robust employment opportunities, particularly straight after graduation. In a discipline like PE, where almost everything that matters takes place thousands of feet underground, apportioning credit for successes or responsibility for failures is itself a challenge. Decreases in student enrollments in PE programs reported by various universities during times of low oil and gas prices poses questions about the future of the PEs discipline, despite the steady demand for oil and gas in the world's energy mix. Academic programs interested in facilitating a smooth transition of their graduates into the industry should work in conjunction with practitioners to provide the correct balance between theory and practice in their coursework ensuring that once employment opportunities are created, they get filled with candidates of relevant education and training.\u0000 PE degree-holding candidates should be the natural first choice for PE positions. This means that their educational and professional backgrounds should be providing them with an undisputed advantage which places them a leg above candidates from other disciplines. For instance, for a well completions job opening, there should not be a better alternative than a good PE specialized in well completions. If every PE graduate comes out of his or her program with a skillset which is superior to that of his or her competition, he or she will be the preferred choice for an oil and gas job.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78520823","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}
Rahmat Ashari, Owen Sorensen, P. Ashok, E. van Oort, M. Isbell, Koda Chovanetz, Nicole Foster
Although numerous studies have investigated how shocks and vibrations contribute to bottomhole assembly (BHA) failures during hole-making, very few have explicitly focused on shock and vibrational behaviors during drillpipe connections. This study adopts a data-driven approach to explore various connection practices and their associated shocks and vibrations, aiming to propose optimum "connection recipes" that minimize negative drillstring impacts during connections. This study utilized data from surface sensors as well as downhole accelerometers and gyroscopes installed both at a downhole sub and the bit. In total, 520 connections from 5 lateral sections were studied. Several quality checks and corrections were performed to ensure synchronization between surface and downhole data. The analyses focused on two connection phases specifically: going off-bottom and going back to bottom. The presence of stick-slip events and high magnitudes of both maximum and root mean squared (RMS) radial accelerations were examined together with the associated surface drilling parameters. Various visualization approaches were performed to help demonstrate the vibration and shock behaviors resulting from different going off-bottom and going back to bottom practices. The analyses showed that restarting surface rotational speed at low values (≤ 40 RPM) risks inducing stick-slip events when going back to bottom. When the surface RPM was increased sufficiently, a notable reduction in RMS radial acceleration was observed. Maximum radial acceleration magnitude was highest before WOB application, which could be mitigated by immediate WOB re-application. Appreciable variation in the maximum radial acceleration was apparent when restarting at low (≤ 15 klbf) WOB values. When going off-bottom, drilling off should be accompanied by a reduction in the surface rotational speed to avoid a jump in the maximum radial acceleration values. This work provides suggestions on how to execute better connections. Since the impacts of shocks and vibrations during connections have previously been largely overlooked, this study fills a knowledge gap to help establish better practices and automation routines to improve the lifespan of the bit and downhole tools.
{"title":"Connection Recipes: Exploring Optimum Connection Practices through a Data-Driven Approach","authors":"Rahmat Ashari, Owen Sorensen, P. Ashok, E. van Oort, M. Isbell, Koda Chovanetz, Nicole Foster","doi":"10.2118/206026-ms","DOIUrl":"https://doi.org/10.2118/206026-ms","url":null,"abstract":"\u0000 Although numerous studies have investigated how shocks and vibrations contribute to bottomhole assembly (BHA) failures during hole-making, very few have explicitly focused on shock and vibrational behaviors during drillpipe connections. This study adopts a data-driven approach to explore various connection practices and their associated shocks and vibrations, aiming to propose optimum \"connection recipes\" that minimize negative drillstring impacts during connections.\u0000 This study utilized data from surface sensors as well as downhole accelerometers and gyroscopes installed both at a downhole sub and the bit. In total, 520 connections from 5 lateral sections were studied. Several quality checks and corrections were performed to ensure synchronization between surface and downhole data. The analyses focused on two connection phases specifically: going off-bottom and going back to bottom. The presence of stick-slip events and high magnitudes of both maximum and root mean squared (RMS) radial accelerations were examined together with the associated surface drilling parameters. Various visualization approaches were performed to help demonstrate the vibration and shock behaviors resulting from different going off-bottom and going back to bottom practices.\u0000 The analyses showed that restarting surface rotational speed at low values (≤ 40 RPM) risks inducing stick-slip events when going back to bottom. When the surface RPM was increased sufficiently, a notable reduction in RMS radial acceleration was observed. Maximum radial acceleration magnitude was highest before WOB application, which could be mitigated by immediate WOB re-application. Appreciable variation in the maximum radial acceleration was apparent when restarting at low (≤ 15 klbf) WOB values. When going off-bottom, drilling off should be accompanied by a reduction in the surface rotational speed to avoid a jump in the maximum radial acceleration values.\u0000 This work provides suggestions on how to execute better connections. Since the impacts of shocks and vibrations during connections have previously been largely overlooked, this study fills a knowledge gap to help establish better practices and automation routines to improve the lifespan of the bit and downhole tools.","PeriodicalId":10965,"journal":{"name":"Day 3 Thu, September 23, 2021","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2021-09-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82092215","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}
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