Uruguay is at the forefront in the use of renewable energy sources and has almost totally decarbonized its electricity matrix, reducing its dependence on fossil fuels. The country is advancing into a second energy transition, including the development of a green Hydrogen (H2) economy. This work presents the Analogies from the Exploration & Production (E&P) business model applied for green H2 developments offshore Uruguay. Considering the sovereignty Uruguay has in activities such as the production of energy from wind in its Exclusive Economic Zone (EEZ), the Uruguayan NOC has based its vision for a sustainable future on the H2U Offshore Round, for which it will offer offshore areas on bidding rounds for energy companies to carry out feasibility studies and potential installation of infrastructure to produce H2 from offshore renewable energy, at their own cost and risk entirely. In this work, the authors elaborated a probabilistic technical and economic model, including all the relevant considerations for the green H2 development project, which was used for the design of the proposed fiscal regime for the H2U Offshore Round. The Uruguayan NOC is managing and articulating the traditional Oil & Gas (O&G) upstream business and the green H2 offshore program together simultaneously, maximizing the synergies among them. The offshore of Uruguay presents a large technical potential and excellent conditions for wind resource, with high wind speed, capacity factors and the availability of large areas. This paper includes the main features of the H2U Offshore Round bidding terms and the contract model, highlighting the synergies and analogies with the E&P projects. In addition, the results of the abovementioned probabilistic model, such as project profitability measures, breakeven hydrogen price and minimum economic capacity factors are presented. In the recent past, Uruguay was able to attract over a billion of US$ of risk capital from the major O&G companies for exploration of hydrocarbons offshore. Hence, the NOC's innovative approach is to bring several similarities from the E&P business to the H2U Offshore Round, with a sound and fair balance between risk and rewards for the energy companies, leading a responsible transition pathway from fossil fuels to green hydrogen in Uruguay.
{"title":"Analogies from the E&P Business Model Applied for Green Hydrogen Developments Offshore Uruguay","authors":"S. Ferro, J. Tomasini, P. Gristo, Rodrigo Novo","doi":"10.4043/32560-ms","DOIUrl":"https://doi.org/10.4043/32560-ms","url":null,"abstract":"\u0000 Uruguay is at the forefront in the use of renewable energy sources and has almost totally decarbonized its electricity matrix, reducing its dependence on fossil fuels. The country is advancing into a second energy transition, including the development of a green Hydrogen (H2) economy. This work presents the Analogies from the Exploration & Production (E&P) business model applied for green H2 developments offshore Uruguay.\u0000 Considering the sovereignty Uruguay has in activities such as the production of energy from wind in its Exclusive Economic Zone (EEZ), the Uruguayan NOC has based its vision for a sustainable future on the H2U Offshore Round, for which it will offer offshore areas on bidding rounds for energy companies to carry out feasibility studies and potential installation of infrastructure to produce H2 from offshore renewable energy, at their own cost and risk entirely. In this work, the authors elaborated a probabilistic technical and economic model, including all the relevant considerations for the green H2 development project, which was used for the design of the proposed fiscal regime for the H2U Offshore Round.\u0000 The Uruguayan NOC is managing and articulating the traditional Oil & Gas (O&G) upstream business and the green H2 offshore program together simultaneously, maximizing the synergies among them. The offshore of Uruguay presents a large technical potential and excellent conditions for wind resource, with high wind speed, capacity factors and the availability of large areas. This paper includes the main features of the H2U Offshore Round bidding terms and the contract model, highlighting the synergies and analogies with the E&P projects. In addition, the results of the abovementioned probabilistic model, such as project profitability measures, breakeven hydrogen price and minimum economic capacity factors are presented.\u0000 In the recent past, Uruguay was able to attract over a billion of US$ of risk capital from the major O&G companies for exploration of hydrocarbons offshore. Hence, the NOC's innovative approach is to bring several similarities from the E&P business to the H2U Offshore Round, with a sound and fair balance between risk and rewards for the energy companies, leading a responsible transition pathway from fossil fuels to green hydrogen in Uruguay.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126283468","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}
4th Industrial Revolution (4IR) technologies have assumed critical importance in the oil and gas industry, enabling data analysis and automation at unprecedented levels. Formation evaluation and reservoir monitoring are crucial areas for optimizing reservoir production, maximizing sweep efficiency and characterizing the reservoirs. Automation, robotics and artificial intelligence (AI) have led to tremendous transformations in these areas. From AI inspired well logging data interpretation to real-time reservoir monitoring, technologies have led to cost savings, increase in efficiencies and infrastructure centralization. In this work we provide an overview of how autoregressive deep learning methodologies can lead to major advances in the field of formation evaluation and reservoir characterization, providing a comprehensive overview of the technologies developed and utilized in this domain. Furthermore, we provide a future outlook for smart technologies in formation evaluation, and how these sensor-derived data can be integrated. This also describes the challenges ahead. Future developments will experience a growing penetration of 4IR technology for enhancing formation evaluation in subsurface reservoirs.
{"title":"An Advanced in-Line Sensing AI Framework for Enhanced Drilling Operations","authors":"Klemens Katterbauer, Abdallah Al Shehri","doi":"10.4043/32248-ms","DOIUrl":"https://doi.org/10.4043/32248-ms","url":null,"abstract":"\u0000 4th Industrial Revolution (4IR) technologies have assumed critical importance in the oil and gas industry, enabling data analysis and automation at unprecedented levels. Formation evaluation and reservoir monitoring are crucial areas for optimizing reservoir production, maximizing sweep efficiency and characterizing the reservoirs. Automation, robotics and artificial intelligence (AI) have led to tremendous transformations in these areas. From AI inspired well logging data interpretation to real-time reservoir monitoring, technologies have led to cost savings, increase in efficiencies and infrastructure centralization. In this work we provide an overview of how autoregressive deep learning methodologies can lead to major advances in the field of formation evaluation and reservoir characterization, providing a comprehensive overview of the technologies developed and utilized in this domain. Furthermore, we provide a future outlook for smart technologies in formation evaluation, and how these sensor-derived data can be integrated. This also describes the challenges ahead. Future developments will experience a growing penetration of 4IR technology for enhancing formation evaluation in subsurface reservoirs.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"126341948","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}
What does energy transition mean? What are we transitioning to? Why now? How long will it take? And how will we get there? The scope of this paper focuses on defining the different drivers and strategies that various entities in the oil and gas industry are utilizing to transform operations and business strategies – specifically segmented to the United States, United Kingdom, and Europe. To operators, the primary focus is to transform their business (influenced by regulations and legislative policies) by reducing their carbon emissions while also investing in cleaner energy sources, such as geothermal, renewables, and hydrogen. For service companies, aside from internal decarbonization, it is another potential revenue stream by offering products, equipment, and services to operators in the ‘energy transition sector’. For ‘developing’ countries, the primary focus is on the fundamental commitment for energy diversification (e.g., energy security) in order to achieve sustainable self-sufficient energy source/s that are less impacted by socio-economical or geo-political factors. In contrast, for ‘developed’ countries, it is net-zero goals and energy security. For example, agencies such as the Department of Energy, offering funding or incentivizing projects on decarbonization, clean energy initiatives, or supporting emerging technologies on renewable and alternative energy. In hindsight, the energy transition shift will have different outcomes to different parties. The main focus in this paper is to break down the ‘buzz word’ associated with energy transition as a popular concept, fettered by technology hype, political agendas, and/or financial influences that are inherently attached to the term ‘energy transition.’ Furthermore, the paper will explain the misconceptions and intricacies behind the strategies that companies, and government agencies are undertaking in this energy paradigm shift. Lastly, emphasis will be made on what is driving this paradigm shift: technology, policy, and cultural change. Further light will be shined on how the industry's previous institutional mindset has changed to a broad, open-minded desire to create a net-positive outcome using Environmental, Social, and Governance techniques.
{"title":"What Does Energy Transition Actually Mean for the Oil & Gas Industry?","authors":"B. Hoxha, A. Nair","doi":"10.4043/32509-ms","DOIUrl":"https://doi.org/10.4043/32509-ms","url":null,"abstract":"\u0000 What does energy transition mean? What are we transitioning to? Why now? How long will it take? And how will we get there? The scope of this paper focuses on defining the different drivers and strategies that various entities in the oil and gas industry are utilizing to transform operations and business strategies – specifically segmented to the United States, United Kingdom, and Europe.\u0000 To operators, the primary focus is to transform their business (influenced by regulations and legislative policies) by reducing their carbon emissions while also investing in cleaner energy sources, such as geothermal, renewables, and hydrogen. For service companies, aside from internal decarbonization, it is another potential revenue stream by offering products, equipment, and services to operators in the ‘energy transition sector’. For ‘developing’ countries, the primary focus is on the fundamental commitment for energy diversification (e.g., energy security) in order to achieve sustainable self-sufficient energy source/s that are less impacted by socio-economical or geo-political factors. In contrast, for ‘developed’ countries, it is net-zero goals and energy security. For example, agencies such as the Department of Energy, offering funding or incentivizing projects on decarbonization, clean energy initiatives, or supporting emerging technologies on renewable and alternative energy.\u0000 In hindsight, the energy transition shift will have different outcomes to different parties. The main focus in this paper is to break down the ‘buzz word’ associated with energy transition as a popular concept, fettered by technology hype, political agendas, and/or financial influences that are inherently attached to the term ‘energy transition.’ Furthermore, the paper will explain the misconceptions and intricacies behind the strategies that companies, and government agencies are undertaking in this energy paradigm shift.\u0000 Lastly, emphasis will be made on what is driving this paradigm shift: technology, policy, and cultural change. Further light will be shined on how the industry's previous institutional mindset has changed to a broad, open-minded desire to create a net-positive outcome using Environmental, Social, and Governance techniques.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128963368","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 number of mature wells worldwide requiring abandonment intervention is rapidly gaining exposure again as the industry recovers. Current access to the completion, using straightforward methods of barriers to satisfy regulatory standards, is the primary means of completing the life cycle of a well. Other methods require an intersect process into the existing wellbore for the abandonment to be considered compliant. Using whipstocks to assist with the intersect can reduce time vs. conventional methods. Traditional methods of intersecting wells involve drilling or milling into the existing wellbore using directional assemblies, usually after a sidetrack operation up hole. This process of trying to breach into the existing well can be problematic and result in multiple unsuccessful attempts, driving up operational spend. Rather than leaving an intersect to chance, a whipstock can be used as a diverter to increase the likelihood of success while also controlling depth and direction more accurately. Once run into the well and anchored, the whipstock also acts as a re-entry guide for intervention and abandonment operations. An in-depth analysis of a recent abandonment operation, where both directional assemblies and eventually a whipstock was used to intersect existing casing for abandonment and to highlight the advantages and pain points associated with both methods. Through detailed preplanning, intensive logging, wellbore preparation, and prior experience, the whipstock operation was successful relative to prior attempts with conventional methods. The intersect and following abandonment process were not completed without lessons learned. Hole conditions, an up-hole casing exit junction, and custom cement blends were a few of the areas of focus for future improvement on efficiency. Even with operational challenges, the whipstock operation reduced time spent intersecting the well. This paper shows that whipstocks are a viable option to reduce time spent intersecting wells for abandonment purposes. This case history provides the industry an opportunity to replicate this success in similar applications.
{"title":"Casing Exit to Casing Entry - A Novel Concept for the Abandonment Process in Intersect Applications","authors":"Tom Emelander, M. Willis","doi":"10.4043/32508-ms","DOIUrl":"https://doi.org/10.4043/32508-ms","url":null,"abstract":"\u0000 The number of mature wells worldwide requiring abandonment intervention is rapidly gaining exposure again as the industry recovers. Current access to the completion, using straightforward methods of barriers to satisfy regulatory standards, is the primary means of completing the life cycle of a well. Other methods require an intersect process into the existing wellbore for the abandonment to be considered compliant. Using whipstocks to assist with the intersect can reduce time vs. conventional methods.\u0000 Traditional methods of intersecting wells involve drilling or milling into the existing wellbore using directional assemblies, usually after a sidetrack operation up hole. This process of trying to breach into the existing well can be problematic and result in multiple unsuccessful attempts, driving up operational spend. Rather than leaving an intersect to chance, a whipstock can be used as a diverter to increase the likelihood of success while also controlling depth and direction more accurately. Once run into the well and anchored, the whipstock also acts as a re-entry guide for intervention and abandonment operations.\u0000 An in-depth analysis of a recent abandonment operation, where both directional assemblies and eventually a whipstock was used to intersect existing casing for abandonment and to highlight the advantages and pain points associated with both methods. Through detailed preplanning, intensive logging, wellbore preparation, and prior experience, the whipstock operation was successful relative to prior attempts with conventional methods. The intersect and following abandonment process were not completed without lessons learned. Hole conditions, an up-hole casing exit junction, and custom cement blends were a few of the areas of focus for future improvement on efficiency. Even with operational challenges, the whipstock operation reduced time spent intersecting the well.\u0000 This paper shows that whipstocks are a viable option to reduce time spent intersecting wells for abandonment purposes. This case history provides the industry an opportunity to replicate this success in similar applications.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133724289","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}
Deanne Hargrave, Gene Bryant, Jack Dow Fraser, Selina Kaur, Inaki Funes Macarro, A. Rabain, Craig Scherschel, Eric Swanson
Atlantic Shores Offshore Wind is developing one of the largest offshore wind energy projects along the U.S. East Coast. Given the large lease area covering 741 km2 and with minimal pre-existing geophysical, geotechnical, environmental, and marine archaeological data availability when the lease was awarded, significant front-end efforts were required to complete project design and regulatory site characterization. Collection of the information needed to progress the Construction Operations Plan and develop a project's detailed design parameters would typically take up to 4 years to finalize. This long duration is exacerbated by the misaligned timing of geophysical information needed early for permitting purposes compared to detailed geotechnical information acquired later, when project design essentials are better defined. This timing issue was managed through innovative phasing and integration of geoscience efforts in the first few years of the development. Coordinated acquisition of geohazards, geophysics, marine archaeology, geotechnics, and benthic habitat data, designed to cover the range of project variables within the project design envelope, optimized the survey campaign and resulted in a future-proof site characterization baseline. This case study highlights various technological, operational and strategic innovations implemented in the following areas: fisheries management and simultaneous vessel operations (SIMOPS), survey line planning, environmental and benthic planning, geotechnical tools and techniques, phased ground model development, data quality assurance and control, offshore operations oversight, data management and regulatory strategies. Refinement to survey plans, including orientation, sequencing, clustering, and multi-purposing data acquisition, delivered multiple efficiencies as the project matured. The team achieved geoscience data quality objectives and reduced survey durations by carefully considering commercial fishing intensity, metocean conditions, geological features, and survey line design or layout. Close coordination with multiple technical package teams was necessary to understand and anticipate evolving engineering data needs and minimize duplicate data gathering. This integrated approach enabled the project to accelerate the identification and interpretation efforts needed to answer critical questions for geotechnical ground modeling, archaeological paleolandscape modeling, geologic history determination, and benthic habitat mapping in ways that are unique and innovative to the offshore wind industry. The unprecedented use of new data displays and innovative mapping tools allowed various project development and engineering design experts from across the global project team to easily access the wealth of geoscientific information developed without the need for specialty software or extensive training. The approach also realized valuable benefits in the areas of offshore safety, achieving critical milestones
{"title":"Offshore Wind Integrated Geoscience Approach Considering Regulatory Requirements and Project Design Essentials to Optimize Timelines Bringing Value to Project, Developer, and Consumer","authors":"Deanne Hargrave, Gene Bryant, Jack Dow Fraser, Selina Kaur, Inaki Funes Macarro, A. Rabain, Craig Scherschel, Eric Swanson","doi":"10.4043/32482-ms","DOIUrl":"https://doi.org/10.4043/32482-ms","url":null,"abstract":"\u0000 Atlantic Shores Offshore Wind is developing one of the largest offshore wind energy projects along the U.S. East Coast. Given the large lease area covering 741 km2 and with minimal pre-existing geophysical, geotechnical, environmental, and marine archaeological data availability when the lease was awarded, significant front-end efforts were required to complete project design and regulatory site characterization. Collection of the information needed to progress the Construction Operations Plan and develop a project's detailed design parameters would typically take up to 4 years to finalize. This long duration is exacerbated by the misaligned timing of geophysical information needed early for permitting purposes compared to detailed geotechnical information acquired later, when project design essentials are better defined. This timing issue was managed through innovative phasing and integration of geoscience efforts in the first few years of the development. Coordinated acquisition of geohazards, geophysics, marine archaeology, geotechnics, and benthic habitat data, designed to cover the range of project variables within the project design envelope, optimized the survey campaign and resulted in a future-proof site characterization baseline.\u0000 This case study highlights various technological, operational and strategic innovations implemented in the following areas: fisheries management and simultaneous vessel operations (SIMOPS), survey line planning, environmental and benthic planning, geotechnical tools and techniques, phased ground model development, data quality assurance and control, offshore operations oversight, data management and regulatory strategies. Refinement to survey plans, including orientation, sequencing, clustering, and multi-purposing data acquisition, delivered multiple efficiencies as the project matured. The team achieved geoscience data quality objectives and reduced survey durations by carefully considering commercial fishing intensity, metocean conditions, geological features, and survey line design or layout. Close coordination with multiple technical package teams was necessary to understand and anticipate evolving engineering data needs and minimize duplicate data gathering.\u0000 This integrated approach enabled the project to accelerate the identification and interpretation efforts needed to answer critical questions for geotechnical ground modeling, archaeological paleolandscape modeling, geologic history determination, and benthic habitat mapping in ways that are unique and innovative to the offshore wind industry. The unprecedented use of new data displays and innovative mapping tools allowed various project development and engineering design experts from across the global project team to easily access the wealth of geoscientific information developed without the need for specialty software or extensive training. The approach also realized valuable benefits in the areas of offshore safety, achieving critical milestones","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116685202","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}
Synthetic oil base drilling muds are re-cycled for cost efficiency and to minimize environmental effects. Invariably, very fine micro-sized magnetic or paramagnetic material from drill-string and casing wear accumulates in the drilling mud over time and cause significant shielding effect on the downhole cross-axial magnetometer sensors. This case study explores various mitigating methods to acquire Measurement-While-Drilling (MWD) surveys within acceptance tolerances and where possible, to define minimum wellbore uncertainties levels depending on the wellbore trajectory relative to earth's magnetics especially at lower latitudes.
{"title":"Magnetic Mud Shielding Effects on Measurement-While-Drilling Azimuth Survey Acceptance Tolerance at Low Latitudes: A Case Study, Malaysia","authors":"K. H. Kok, Andrew Jen, Poppoom Tipdontree","doi":"10.4043/32222-ms","DOIUrl":"https://doi.org/10.4043/32222-ms","url":null,"abstract":"\u0000 Synthetic oil base drilling muds are re-cycled for cost efficiency and to minimize environmental effects. Invariably, very fine micro-sized magnetic or paramagnetic material from drill-string and casing wear accumulates in the drilling mud over time and cause significant shielding effect on the downhole cross-axial magnetometer sensors. This case study explores various mitigating methods to acquire Measurement-While-Drilling (MWD) surveys within acceptance tolerances and where possible, to define minimum wellbore uncertainties levels depending on the wellbore trajectory relative to earth's magnetics especially at lower latitudes.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"133319124","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}
Enhanced seismic velocity models (e.g. semblance or tomography) are key inputs for greenfield pore pressure prediction (PPP) in clastic basins, enabling velocity extraction along the planned well-path and also from a 3d earth-model surrounding the drill-site to test sensitivities and ranges. If velocity model resolution is sufficient, the resultant pressure gradients extracted along interpreted stratigraphic horizons from one of these three-dimensional (3D) earth models yields valuable insights into lateral pressure transfer efficacy, thus informing the net-to-gross (e.g. reservoir presence or absence) for the interval. The following inputs are required: 1) 3D seismic velocity model; 2) locally calibrated transforms for Compressional Velocity (Vp) to Vertical Effective Stress (VES) to generate a 3D pressure model from seismic velocities; 3) high-quality seismic interpretation horizons. The critical step is to extract from the 3D pressure model the pressure along each mapped horizon and plot the pressure with depth for each. For a shale horizon, the result reflects a linear shale gradient (e.g. ~0.83 psi/ft) consistent with restricted lateral pressure communication. Conversely, extraction along sand-interval yields a brine gradient (e.g., ~0.47 psi/ft) indicative of effective lateral pressure communication. Two Deepwater Gulf of Mexico (GOM) salt-withdrawal clastic mini-basins are depicted in seismic cross-section, each with representative suite of interpreted seismic horizons for pressure analysis within the depth-range of interest. It is not apparent to the uncalibrated-eye, in lieu of well data, which of the two is reservoir-prone and which is reservoir-absent. A detailed summary of methods and assumptions will follow, including empirical transforms, seismic earth cube generation, map-based extraction, and pressure gradient plots. The resultant gradient plots reveal one basin with uniform brine gradients and ubiquitous lateral pressure communication, compared with a suite of exclusively shale gradients in the other. Finally, well results, one test from each basin, confirm ubiquitous reservoir in the basin with the predicted brine gradients, contrasted with absence of reservoir in the basin with shale gradients. Following the presentation, the audience will require nothing more than graphical inspection of the event-extracted pressure gradient plots to discriminate a sand interval from a shale, and a reservoir-prone mini-basin from a reservoir-lean one.
{"title":"Predicting Reservoir Presence from Seismic Velocity Mapping and Pore Pressure Prediction","authors":"M. Legg","doi":"10.4043/32393-ms","DOIUrl":"https://doi.org/10.4043/32393-ms","url":null,"abstract":"\u0000 Enhanced seismic velocity models (e.g. semblance or tomography) are key inputs for greenfield pore pressure prediction (PPP) in clastic basins, enabling velocity extraction along the planned well-path and also from a 3d earth-model surrounding the drill-site to test sensitivities and ranges. If velocity model resolution is sufficient, the resultant pressure gradients extracted along interpreted stratigraphic horizons from one of these three-dimensional (3D) earth models yields valuable insights into lateral pressure transfer efficacy, thus informing the net-to-gross (e.g. reservoir presence or absence) for the interval. The following inputs are required: 1) 3D seismic velocity model; 2) locally calibrated transforms for Compressional Velocity (Vp) to Vertical Effective Stress (VES) to generate a 3D pressure model from seismic velocities; 3) high-quality seismic interpretation horizons. The critical step is to extract from the 3D pressure model the pressure along each mapped horizon and plot the pressure with depth for each. For a shale horizon, the result reflects a linear shale gradient (e.g. ~0.83 psi/ft) consistent with restricted lateral pressure communication. Conversely, extraction along sand-interval yields a brine gradient (e.g., ~0.47 psi/ft) indicative of effective lateral pressure communication. Two Deepwater Gulf of Mexico (GOM) salt-withdrawal clastic mini-basins are depicted in seismic cross-section, each with representative suite of interpreted seismic horizons for pressure analysis within the depth-range of interest. It is not apparent to the uncalibrated-eye, in lieu of well data, which of the two is reservoir-prone and which is reservoir-absent. A detailed summary of methods and assumptions will follow, including empirical transforms, seismic earth cube generation, map-based extraction, and pressure gradient plots. The resultant gradient plots reveal one basin with uniform brine gradients and ubiquitous lateral pressure communication, compared with a suite of exclusively shale gradients in the other. Finally, well results, one test from each basin, confirm ubiquitous reservoir in the basin with the predicted brine gradients, contrasted with absence of reservoir in the basin with shale gradients. Following the presentation, the audience will require nothing more than graphical inspection of the event-extracted pressure gradient plots to discriminate a sand interval from a shale, and a reservoir-prone mini-basin from a reservoir-lean one.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"128792678","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}
K. Husby, A. Saasen, J. D. Ytrehus, M. Hjelstuen, Mostafa Koraei, A. Liberale, T. Eriksen
During the well intercept drilling enterprise, several wireline logging operations are being run. The drill pipe is pulled out of the well and a wireline tool is run in. From the wireline tool a very low frequency alternating current is emitted into the formation to reach the target well casing. Then the electric current runs down the casing and back into the bottom of the relief well. This current set up a variable magnetic field that is measured by magnetometers in the relief well. Thus, the direction towards the target well can be determined. The drilling direction is accordingly adjusted, and drilling is continued. Typically, a number of 10 – 25 similar wireline navigation runs are needed before the target well is intercepted. The operation with pulling drill pipe out of the well, running the wireline operation and finally running the drill string back into the well typically cost several days drilling time. A prototype of a tool for Active Magnetic Ranging While Drilling has been developed. The scope of using this tool is to perform similar logging operations as currently being performed with the wireline operations, with an integrated tool systems on the relief well drill pipe. Thus, all the tripping operations are avoided and the time to drill the relief well is significantly reduced. This tool is described in detail in the following. Focus will be given to performance tests conducted in the laboratory and in a research well in Norway. A drill pipe is placed in a target well. Then a drill pipe including the measurement tool is run in a neighbour well and the direction and distance to the target well is measured. The set-up and results of this logging operation conducted on a drill pipe is described in detail.
{"title":"Active Magnetic Ranging While Drilling: Performance Test","authors":"K. Husby, A. Saasen, J. D. Ytrehus, M. Hjelstuen, Mostafa Koraei, A. Liberale, T. Eriksen","doi":"10.4043/32475-ms","DOIUrl":"https://doi.org/10.4043/32475-ms","url":null,"abstract":"\u0000 During the well intercept drilling enterprise, several wireline logging operations are being run. The drill pipe is pulled out of the well and a wireline tool is run in. From the wireline tool a very low frequency alternating current is emitted into the formation to reach the target well casing. Then the electric current runs down the casing and back into the bottom of the relief well. This current set up a variable magnetic field that is measured by magnetometers in the relief well. Thus, the direction towards the target well can be determined. The drilling direction is accordingly adjusted, and drilling is continued. Typically, a number of 10 – 25 similar wireline navigation runs are needed before the target well is intercepted. The operation with pulling drill pipe out of the well, running the wireline operation and finally running the drill string back into the well typically cost several days drilling time. A prototype of a tool for Active Magnetic Ranging While Drilling has been developed. The scope of using this tool is to perform similar logging operations as currently being performed with the wireline operations, with an integrated tool systems on the relief well drill pipe. Thus, all the tripping operations are avoided and the time to drill the relief well is significantly reduced. This tool is described in detail in the following. Focus will be given to performance tests conducted in the laboratory and in a research well in Norway. A drill pipe is placed in a target well. Then a drill pipe including the measurement tool is run in a neighbour well and the direction and distance to the target well is measured. The set-up and results of this logging operation conducted on a drill pipe is described in detail.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116001725","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}
Eric Swanson, Craig Scherschel, Jack Fraser, Neil N Puckett, S. Joy, Kieran Blacker
The purpose of this paper is to present the refined and novel components that comprise a methodological proposal of the best practice for the larger paleolandscape reconstruction process in offshore wind development during Site Characterization. To accomplish this goal, several methods were used to bring subject matter experts together to discuss the needs and objectives relative to regulatory compliance, cultural interest, and engineering design in a multi-phase programmatic and survey process. The expansive results from this modeling approach have allowed Qualified Marine Archaeologists (QMAs) to develop, in collaboration with geologists and engineers, the paleolandscape ground model ahead of typical developments by several months. The produced data innovatively multiplied available metrics, allowing adjustment of the regional geologic timeline to date marine Transgressive Channel Groups (TCGs) in the area and allowed better sequencing of the late Pleistocene and corrected some gaps in the region's depositional sequence model. With the resulting ground model, archaeologists, geologists, and engineers improved comprehensive qualitative analyses that can assist with understanding the impacts that anthropogenic activities have in the region. The novel and additive information that this research offers is multi-fold. The methods employed here can aid in reducing challenges and delays associated with traditional non-multi-phase approaches when adopted by other developers or researchers in the offshore space. The efficiency-oriented outcome of adopting this method can reduce larger systematic problems caused by a lack of industry coordination practices in reporting to various engineering and regulatory bodies. They also isolate key features and processes that happen very early on in the process and maximize efficiency by gathering data needed many months to years later in the process. Another additive benefit was the approach of gathering data in the least intrusive and destructive way possible to maximize the knowledge that development and archaeological groups bring to the table when having conversations with consulting parties and government stakeholders. The novelty of this process has expanded synthesis in a way that starts the process early enough that the subject matter experts (SMEs) can develop a robust working ground model while considering multiple components at the same time, rather than teams working in a silo, uninformed of each other's work. The use of this process can grow the project methodology and industry best practice for multiple developers and government entities into the future.
{"title":"Using Geophysics and Geotechnics to Maximize the Building of a Paleolandscape Reconstruction for Both an Archaeological and Geological History","authors":"Eric Swanson, Craig Scherschel, Jack Fraser, Neil N Puckett, S. Joy, Kieran Blacker","doi":"10.4043/32533-ms","DOIUrl":"https://doi.org/10.4043/32533-ms","url":null,"abstract":"\u0000 The purpose of this paper is to present the refined and novel components that comprise a methodological proposal of the best practice for the larger paleolandscape reconstruction process in offshore wind development during Site Characterization. To accomplish this goal, several methods were used to bring subject matter experts together to discuss the needs and objectives relative to regulatory compliance, cultural interest, and engineering design in a multi-phase programmatic and survey process.\u0000 The expansive results from this modeling approach have allowed Qualified Marine Archaeologists (QMAs) to develop, in collaboration with geologists and engineers, the paleolandscape ground model ahead of typical developments by several months. The produced data innovatively multiplied available metrics, allowing adjustment of the regional geologic timeline to date marine Transgressive Channel Groups (TCGs) in the area and allowed better sequencing of the late Pleistocene and corrected some gaps in the region's depositional sequence model. With the resulting ground model, archaeologists, geologists, and engineers improved comprehensive qualitative analyses that can assist with understanding the impacts that anthropogenic activities have in the region.\u0000 The novel and additive information that this research offers is multi-fold. The methods employed here can aid in reducing challenges and delays associated with traditional non-multi-phase approaches when adopted by other developers or researchers in the offshore space. The efficiency-oriented outcome of adopting this method can reduce larger systematic problems caused by a lack of industry coordination practices in reporting to various engineering and regulatory bodies. They also isolate key features and processes that happen very early on in the process and maximize efficiency by gathering data needed many months to years later in the process. Another additive benefit was the approach of gathering data in the least intrusive and destructive way possible to maximize the knowledge that development and archaeological groups bring to the table when having conversations with consulting parties and government stakeholders. The novelty of this process has expanded synthesis in a way that starts the process early enough that the subject matter experts (SMEs) can develop a robust working ground model while considering multiple components at the same time, rather than teams working in a silo, uninformed of each other's work. The use of this process can grow the project methodology and industry best practice for multiple developers and government entities into the future.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116983322","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}
Junzhe Wang, E. Ozbayoglu, Silvio Baldino, Yaxin Liu, Danzhu Zheng
Fast and accurate kick detection during drilling operations is critical to ensure drilling safety and reduce non-productive time. Over the years, the industry has taken various approaches to address this problem. However, due to the complexity of the influx process, the problem of slow detection speed and high false detection rate still exists. While many recent works of literature have attempted to solve the influx detection problem with machine learning algorithms, only a few of them have considered the time series information in real-time drilling data. Since there may be lags of unknown duration between different drilling parameters, a properly designed time series analysis model may be able to capture their relationships and make reasonable predictions. Recurrent Neural Network with long short-term memory (RNN-LSTM) architecture is a deep learning algorithm capable of making predictions based on historical time series data. Previous studies have shown that the RNN-LSTM algorithms can be applied to real-time drilling data to reasonably predict the trends of a segment of drilling data such as the total mud pit volume. In this paper, several sensitive influx indicators are separately predicted by completely independent RNN-LSTM models based on different sets of real-time drilling parameters. These models run as ensemble learning models to continuously predict influx indicators. Then, the prediction results will be quantified, and the probability of kicks will be calculated based on the different weights for each indicator. The proposed model is tested on field data in parallel with some common kick detection models and the performance is analyzed. It is concluded that the proposed model can perform accurate influx detection and outperform some common methods in the industry in terms of detection speed.
在钻井作业中，快速、准确地检测井涌是确保钻井安全、减少非生产时间的关键。多年来，该行业采取了各种方法来解决这个问题。但是，由于流入过程的复杂性，仍然存在检测速度慢、误检率高的问题。虽然最近的许多文献都试图用机器学习算法解决井涌检测问题，但只有少数文献考虑了实时钻井数据中的时间序列信息。由于不同钻井参数之间可能存在未知持续时间的滞后，因此设计合理的时间序列分析模型可以捕捉它们之间的关系，并做出合理的预测。RNN-LSTM (Recurrent Neural Network with long - short- memory)是一种基于历史时间序列数据进行预测的深度学习算法。已有研究表明，RNN-LSTM算法可以应用于实时钻井数据中，合理预测一段钻井数据的变化趋势，如泥坑总容积。本文基于不同的实时钻井参数集，采用完全独立的RNN-LSTM模型分别预测了几个敏感的流入指标。这些模型作为集成学习模型运行，以连续预测流入指标。然后对预测结果进行量化，并根据各指标的不同权重计算踢脚概率。将该模型与几种常用的井涌检测模型进行了现场数据并行测试，并对其性能进行了分析。实验结果表明，该模型可以实现准确的井涌检测，并且在检测速度上优于业内一些常用方法。
{"title":"Time Series Data Analysis with Recurrent Neural Network for Early Kick Detection","authors":"Junzhe Wang, E. Ozbayoglu, Silvio Baldino, Yaxin Liu, Danzhu Zheng","doi":"10.4043/32428-ms","DOIUrl":"https://doi.org/10.4043/32428-ms","url":null,"abstract":"\u0000 Fast and accurate kick detection during drilling operations is critical to ensure drilling safety and reduce non-productive time. Over the years, the industry has taken various approaches to address this problem. However, due to the complexity of the influx process, the problem of slow detection speed and high false detection rate still exists. While many recent works of literature have attempted to solve the influx detection problem with machine learning algorithms, only a few of them have considered the time series information in real-time drilling data. Since there may be lags of unknown duration between different drilling parameters, a properly designed time series analysis model may be able to capture their relationships and make reasonable predictions. Recurrent Neural Network with long short-term memory (RNN-LSTM) architecture is a deep learning algorithm capable of making predictions based on historical time series data. Previous studies have shown that the RNN-LSTM algorithms can be applied to real-time drilling data to reasonably predict the trends of a segment of drilling data such as the total mud pit volume. In this paper, several sensitive influx indicators are separately predicted by completely independent RNN-LSTM models based on different sets of real-time drilling parameters. These models run as ensemble learning models to continuously predict influx indicators. Then, the prediction results will be quantified, and the probability of kicks will be calculated based on the different weights for each indicator. The proposed model is tested on field data in parallel with some common kick detection models and the performance is analyzed. It is concluded that the proposed model can perform accurate influx detection and outperform some common methods in the industry in terms of detection speed.","PeriodicalId":196855,"journal":{"name":"Day 2 Tue, May 02, 2023","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-04-24","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125859746","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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