Shanli Zhang, Chi Zhang, H. Santo, M. Cai, M. Si, Jixing Cao, S. Quek
A development of physics-based digital twinning of a generic jack-up platform is presented in this paper. Due to lack of field measurement data, a generic large-scale jack-up model was designed, fabricated and tested in TCOMS ocean basin at 1:30 scale under different configurations, with the objective to provide high-quality datasets to validate the proposed digital twin methodologies. The framework and the performance of the digital twin are demonstrated using a realistic and representative basin-scale model as a proof-of-concept. Fundamental to any physics-based digital twins is the establishment of numerical models capable of reproducing consistent behaviors and responses of the physical assets. For this digital twin development, a full order model (FOM) and a reduced order model (ROM) are established. In view of uncertainties associated with the physical asset and numerical modelling, e.g., foundation fixities, leg stiffness, leg-hull connection stiffness and hydrodynamic coefficients, model updating or system identification is performed using the ROM to identify the parameters with relatively large uncertainties. A mapping between the parameters and the associated responses of the FOM and the ROM is subsequently established. After the model updating is completed with the identified parameters, good agreement in terms of the structural responses between the model test and numerical results can be achieved. Both the FOM and ROM are able to reproduce structural responses with good accuracy when compared to physical measurements. The ROM, being a linear structural model based on modal responses, is unable to account for larger non-linear effects due to spudcan fixities, if any. Nevertheless, the ROM is suitable for fatigue evaluation considering fast computational speed and validity of the piecewise linear constraints as assumed for the foundation. The FOM, being less computationally efficient, is suitable for strength evaluation and able to account for any non-linear structural behaviors. The results of boundary displacements from the global dynamic response analysis can be mapped to a detailed local joint model to derive the hotspots stress for a more accurate fatigue evaluation. The digital twin framework for fatigue and strength evaluations based on measured wave loading is demonstrated for a better structural integrity management. As an emerging technology, digital twin will provide visibility of structural health condition to facilitate the transition from preventive to predictive and reliability-centered maintenance strategies. Although the digital twin framework presented in the paper makes use of a representative jack-up at model-scale, the proposed methodology can be potentially applied to full-scale operating jack-ups.
{"title":"Digital Twin of a Generic Jack-Up Platform","authors":"Shanli Zhang, Chi Zhang, H. Santo, M. Cai, M. Si, Jixing Cao, S. Quek","doi":"10.4043/32221-ms","DOIUrl":"https://doi.org/10.4043/32221-ms","url":null,"abstract":"\u0000 A development of physics-based digital twinning of a generic jack-up platform is presented in this paper. Due to lack of field measurement data, a generic large-scale jack-up model was designed, fabricated and tested in TCOMS ocean basin at 1:30 scale under different configurations, with the objective to provide high-quality datasets to validate the proposed digital twin methodologies. The framework and the performance of the digital twin are demonstrated using a realistic and representative basin-scale model as a proof-of-concept.\u0000 Fundamental to any physics-based digital twins is the establishment of numerical models capable of reproducing consistent behaviors and responses of the physical assets. For this digital twin development, a full order model (FOM) and a reduced order model (ROM) are established. In view of uncertainties associated with the physical asset and numerical modelling, e.g., foundation fixities, leg stiffness, leg-hull connection stiffness and hydrodynamic coefficients, model updating or system identification is performed using the ROM to identify the parameters with relatively large uncertainties. A mapping between the parameters and the associated responses of the FOM and the ROM is subsequently established.\u0000 After the model updating is completed with the identified parameters, good agreement in terms of the structural responses between the model test and numerical results can be achieved. Both the FOM and ROM are able to reproduce structural responses with good accuracy when compared to physical measurements. The ROM, being a linear structural model based on modal responses, is unable to account for larger non-linear effects due to spudcan fixities, if any. Nevertheless, the ROM is suitable for fatigue evaluation considering fast computational speed and validity of the piecewise linear constraints as assumed for the foundation. The FOM, being less computationally efficient, is suitable for strength evaluation and able to account for any non-linear structural behaviors. The results of boundary displacements from the global dynamic response analysis can be mapped to a detailed local joint model to derive the hotspots stress for a more accurate fatigue evaluation. The digital twin framework for fatigue and strength evaluations based on measured wave loading is demonstrated for a better structural integrity management.\u0000 As an emerging technology, digital twin will provide visibility of structural health condition to facilitate the transition from preventive to predictive and reliability-centered maintenance strategies. Although the digital twin framework presented in the paper makes use of a representative jack-up at model-scale, the proposed methodology can be potentially applied to full-scale operating jack-ups.","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":"114388856","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}
Fengyuan Zhang, Qiang Zhang, Zhengxin Zhang, Z. Rui, Yueliang Liu, Wei Zhang, X. Zheng, F. Torabi, A. Afanasyev
Experimental methods for core plug analysis are widely used to measure formation permeability under steady-state flow or unsteady state flow conditions, which provides important geoscience information on formation properties. However, typical laboratory techniques hardly reproduce the two-phase water and hydrocarbon storage and transport conditions that formation is subject to in reality. Accordingly, we presented an integrated experimental core analysis method for permeability measurement, which better reproduces these two-phase conditions. The proposed experimental method consists of two-phase fluid initialization and production test, during which the gas rate, liquid rate, and inlet/outlet pressure of the core plug are recorded simultaneously. After constructing with uniform distribution of gas and liquid, the core sample is transformed into a two-phase production process under the conditions of variable rate and sealed boundary. Rate transient analysis is performed to estimate formation permeability with the gathered two-phase rate decline and pressure data. A two-phase diagnostic plot and specialty plot are introduced to identify flow regimes and extract permeability from the slope of a straight line during the experimental data analysis. In this paper, commercial software is used to generate synthetic data for the production test of a core plug. The simulation of two-phase fluid initialization and production tests were conducted on core plugs. The simulation results show a unit-slope straight line on the generated diagnostic plot, which indicates a clear boundary-dominated flow (BDF) regime. By performing a straight-line analysis, we calculated the permeability of the core plug with the slope of straight-line period on specialty plot. The good match of the calculated permeability with the reference value confirms the accuracy of the proposed experimental method with the relative error less than 10%. In addition, the proposed two-phase core analysis method can enormously accelerate test-time, as the permeability of selected rock sample can be estimated in less than 10 minutes. Instead of measuring permeability only under the condition of single phase flow, this paper presents a laboratory technique that combines the experiment of small-diameter core production test under two-phase flow with rate transient analysis method. Unlike prior experimental techniques, the proposed method reproduces the more realistic condition of two-phase flow in the formation during permeability measurement. The two-phase core analysis method achieves the objective of accurate and fast characterization of formation permeability, which is a more "apples to apples" comparison between the fluid flow in the actual reservoir and the core plug.
{"title":"A New Experimental Core Analysis Method for Formation Permeability Measurement Under Two-Phase Condition","authors":"Fengyuan Zhang, Qiang Zhang, Zhengxin Zhang, Z. Rui, Yueliang Liu, Wei Zhang, X. Zheng, F. Torabi, A. Afanasyev","doi":"10.4043/32249-ms","DOIUrl":"https://doi.org/10.4043/32249-ms","url":null,"abstract":"\u0000 Experimental methods for core plug analysis are widely used to measure formation permeability under steady-state flow or unsteady state flow conditions, which provides important geoscience information on formation properties. However, typical laboratory techniques hardly reproduce the two-phase water and hydrocarbon storage and transport conditions that formation is subject to in reality. Accordingly, we presented an integrated experimental core analysis method for permeability measurement, which better reproduces these two-phase conditions.\u0000 The proposed experimental method consists of two-phase fluid initialization and production test, during which the gas rate, liquid rate, and inlet/outlet pressure of the core plug are recorded simultaneously. After constructing with uniform distribution of gas and liquid, the core sample is transformed into a two-phase production process under the conditions of variable rate and sealed boundary. Rate transient analysis is performed to estimate formation permeability with the gathered two-phase rate decline and pressure data. A two-phase diagnostic plot and specialty plot are introduced to identify flow regimes and extract permeability from the slope of a straight line during the experimental data analysis.\u0000 In this paper, commercial software is used to generate synthetic data for the production test of a core plug. The simulation of two-phase fluid initialization and production tests were conducted on core plugs. The simulation results show a unit-slope straight line on the generated diagnostic plot, which indicates a clear boundary-dominated flow (BDF) regime. By performing a straight-line analysis, we calculated the permeability of the core plug with the slope of straight-line period on specialty plot. The good match of the calculated permeability with the reference value confirms the accuracy of the proposed experimental method with the relative error less than 10%. In addition, the proposed two-phase core analysis method can enormously accelerate test-time, as the permeability of selected rock sample can be estimated in less than 10 minutes.\u0000 Instead of measuring permeability only under the condition of single phase flow, this paper presents a laboratory technique that combines the experiment of small-diameter core production test under two-phase flow with rate transient analysis method. Unlike prior experimental techniques, the proposed method reproduces the more realistic condition of two-phase flow in the formation during permeability measurement. The two-phase core analysis method achieves the objective of accurate and fast characterization of formation permeability, which is a more \"apples to apples\" comparison between the fluid flow in the actual reservoir and the core plug.","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":"116849285","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}
On the sea floor of specific deep ocean environments lie prolific amounts of polymetallic nodules that contain minerals critical to meeting the future energy demands of a growing worldwide population. Polymetallic nodules rich in manganese, nickel, and cobalt spread over millions of square kilometers of abyssal seabed and contain the minerals needed for future energy storage demands. The offshore oil and gas industry seeks to participate in the energy expansion by leveraging its deepwater experience to harvest these nodules. The knowledge and wisdom gained from decades of operating offshore provides significant insight into the development and implementation of the technology needed to address the challenges of deep sea nodule harvesting. The authors describe a design selection tool based on the methods described by Stuart Pugh to select a polymetallic nodule Vertical Transport System. Stuart Pugh, known for his work in product design and development, introduced the Pugh Method in the 1980s. The Pugh Method is a structured and integrated process applied to design development including concept generation, evaluation, and selection. The Vertical Transport System design processes uses the Pugh Method to recommend a candidate design. The evaluation step uses a two groups of company experts who present the concepts (the team), and collectively evaluate (the group) and recommend the best design concept for further development. We apply the method to the case of deep sea mineral recovery operations specifically the design of the Vertical Transportation System. First, the authors introduce the Pugh Method tool, how it works, and how it applies to this specific case. We describe how risks and rewards relate to each selection characteristic used to evaluate the Vertical Transport System concepts. Further, we talk about team selection and the points to consider when assembling the right team to achieve credible results. Next, we describe each concept identifying and recognizing the various technical, operational, and economic selection characteristics, such as size, power consumption, reliability, availability, etc. Finally, we evaluate each concept against the different selection characteristics and discuss the results. The paper concludes with a robust process flow chart describing the selection method for a Vertical Transport System.
{"title":"Using the Pugh Method to Select a Polymetallic Nodule Vertical Transport System","authors":"A. Barr","doi":"10.4043/32426-ms","DOIUrl":"https://doi.org/10.4043/32426-ms","url":null,"abstract":"\u0000 On the sea floor of specific deep ocean environments lie prolific amounts of polymetallic nodules that contain minerals critical to meeting the future energy demands of a growing worldwide population. Polymetallic nodules rich in manganese, nickel, and cobalt spread over millions of square kilometers of abyssal seabed and contain the minerals needed for future energy storage demands. The offshore oil and gas industry seeks to participate in the energy expansion by leveraging its deepwater experience to harvest these nodules. The knowledge and wisdom gained from decades of operating offshore provides significant insight into the development and implementation of the technology needed to address the challenges of deep sea nodule harvesting.\u0000 The authors describe a design selection tool based on the methods described by Stuart Pugh to select a polymetallic nodule Vertical Transport System. Stuart Pugh, known for his work in product design and development, introduced the Pugh Method in the 1980s. The Pugh Method is a structured and integrated process applied to design development including concept generation, evaluation, and selection. The Vertical Transport System design processes uses the Pugh Method to recommend a candidate design. The evaluation step uses a two groups of company experts who present the concepts (the team), and collectively evaluate (the group) and recommend the best design concept for further development. We apply the method to the case of deep sea mineral recovery operations specifically the design of the Vertical Transportation System. First, the authors introduce the Pugh Method tool, how it works, and how it applies to this specific case. We describe how risks and rewards relate to each selection characteristic used to evaluate the Vertical Transport System concepts. Further, we talk about team selection and the points to consider when assembling the right team to achieve credible results. Next, we describe each concept identifying and recognizing the various technical, operational, and economic selection characteristics, such as size, power consumption, reliability, availability, etc. Finally, we evaluate each concept against the different selection characteristics and discuss the results. The paper concludes with a robust process flow chart describing the selection method for a Vertical Transport System.","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":"124517294","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}
R. Bosler, Simen Rønne, David Furmidge, Alfhild Waeroe, Johann Rangua, Craig Ferguson
The proposed paper presents a novel method of sampling potential polymetallic nodule and manganese crust extraction sites that improves the efficiency and effectiveness of the campaign when compared to traditional surveying methods. The new method utilizes a work-class ROV to perform survey sampling and testing tasks at a relatively large number of sites per dive. The ROV platform enables the use of precision measurement devices such as high-resolution sonar, cone penetrometer test (CPT) systems and core drilling machines to take in-situ samples and measurements. An ROV mounted skid with integrated sample storage drawers allows samples to be taken from numerous sites using ROV resources and manipulators. Transiting from sample site to sample site at depth improves the efficiency of sampling campaigns especially at very deep polymetallic nodule fields up to 6000 meters deep. Initial studies have shown that high resolution sonar scans can measure nodule abundance and size with sufficient accuracy over a much greater area in less time when compared to traditional box coring methods. Studies of nodule and manganese crust sampling campaign durations have shown that transiting from site to site with the ROV at depth reduces the total duration of a representative sampling campaign by 50% or more. Incorporation of a high accuracy CPT system onto the ROV skid enables in-situ geotechnical testing at depth that are more accurate than the traditional method of measuring sub-core samples taken from box core samples at surface laboratories. For manganese crust fields, a novel core sampling drill rig is capable of drilling core holes on sea floor slopes from 0 – 90° without the need for the ROV to land. These advantages combined with the adaptable capability of manipulator systems to collect samples and the ability to provide high-definition video footage of seafloor topology will result in significant improvements to the efficiency and quality of polymetallic nodule and manganese crust site evaluation. The expected gains in cost and accuracy of assessing deep-sea mineral resources will accelerate the pace of material extraction projects and allow greater investment in marine mineral extraction projects due to greater confidence of project success.
{"title":"Efficient Survey Tools for an Improved Understanding of Deep Seabed Minerals","authors":"R. Bosler, Simen Rønne, David Furmidge, Alfhild Waeroe, Johann Rangua, Craig Ferguson","doi":"10.4043/32490-ms","DOIUrl":"https://doi.org/10.4043/32490-ms","url":null,"abstract":"\u0000 The proposed paper presents a novel method of sampling potential polymetallic nodule and manganese crust extraction sites that improves the efficiency and effectiveness of the campaign when compared to traditional surveying methods.\u0000 The new method utilizes a work-class ROV to perform survey sampling and testing tasks at a relatively large number of sites per dive. The ROV platform enables the use of precision measurement devices such as high-resolution sonar, cone penetrometer test (CPT) systems and core drilling machines to take in-situ samples and measurements. An ROV mounted skid with integrated sample storage drawers allows samples to be taken from numerous sites using ROV resources and manipulators. Transiting from sample site to sample site at depth improves the efficiency of sampling campaigns especially at very deep polymetallic nodule fields up to 6000 meters deep.\u0000 Initial studies have shown that high resolution sonar scans can measure nodule abundance and size with sufficient accuracy over a much greater area in less time when compared to traditional box coring methods. Studies of nodule and manganese crust sampling campaign durations have shown that transiting from site to site with the ROV at depth reduces the total duration of a representative sampling campaign by 50% or more. Incorporation of a high accuracy CPT system onto the ROV skid enables in-situ geotechnical testing at depth that are more accurate than the traditional method of measuring sub-core samples taken from box core samples at surface laboratories. For manganese crust fields, a novel core sampling drill rig is capable of drilling core holes on sea floor slopes from 0 – 90° without the need for the ROV to land. These advantages combined with the adaptable capability of manipulator systems to collect samples and the ability to provide high-definition video footage of seafloor topology will result in significant improvements to the efficiency and quality of polymetallic nodule and manganese crust site evaluation.\u0000 The expected gains in cost and accuracy of assessing deep-sea mineral resources will accelerate the pace of material extraction projects and allow greater investment in marine mineral extraction projects due to greater confidence of project success.","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":"128719405","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}
F. Fernandes, A. Braga, Petrobras Ant°audio Soares
Identification of no-flow zones and mechanical formation damage management are essential for a successful exploratory and production campaign during the development of an oil field. This work develops a new unsteady-state two-dimensional (2-D) integro-differential solution for permeability loss monitoring in a well near an infinite sealing fault. The model presented in this study allows solving the nonlinear hydraulic diffusivity equation (NHDE) with the oil source term. The proper Green's Function (GF) for an infinite sealed barrier represents the well's instantaneous oil point-source/sink effect. Based on image method (IM), the pressure field for the constant permeability solution is given by the sum of two exponential integral functions Ei(tD). However, this solution does not consider the nonlinear effect caused by pressure-sensitive permeability loss. A new deviation factor ξ(p) is derived and coupled to an asymptotic first-order series expansion to deal with this phenomenon. The model also allows for evaluating the oil flow rate influence on the permeability loss during the well-reservoir production curve. Sensitivity analysis investigates the parameters that highly influence the diffusivity deviation factor. Pressure and permeability input data were obtained through a uni-axial test performed in two sandstone layers of the same reservoir rock in an offshore field in Brazil. The analytical solution addressed in this paper was calibrated by a porous media oil flow simulator named IMEX®, broadly used in reservoir engineering works, and the results were accurate. The results present the instantaneous permeability decay effect by a deviation compared to the linear solution in a semi-log plot. The main advantages of the proposed solution are the accuracy, availability of a comprehensive table of the GFs, ease of implementation, and computational cost savings. It constitutes a valuable and attractive mathematical tool to calibrate new models and support well-reservoir performance management.
{"title":"Unsteady-State Mechanical Formation Damage Modeling in Pressure-Sensitive Oil Reservoirs Near No-Flow Boundaries Using a Coupled-Integro-Differential-Perturbation Method","authors":"F. Fernandes, A. Braga, Petrobras Ant°audio Soares","doi":"10.4043/32253-ms","DOIUrl":"https://doi.org/10.4043/32253-ms","url":null,"abstract":"\u0000 Identification of no-flow zones and mechanical formation damage management are essential for a successful exploratory and production campaign during the development of an oil field. This work develops a new unsteady-state two-dimensional (2-D) integro-differential solution for permeability loss monitoring in a well near an infinite sealing fault. The model presented in this study allows solving the nonlinear hydraulic diffusivity equation (NHDE) with the oil source term. The proper Green's Function (GF) for an infinite sealed barrier represents the well's instantaneous oil point-source/sink effect. Based on image method (IM), the pressure field for the constant permeability solution is given by the sum of two exponential integral functions Ei(tD). However, this solution does not consider the nonlinear effect caused by pressure-sensitive permeability loss. A new deviation factor ξ(p) is derived and coupled to an asymptotic first-order series expansion to deal with this phenomenon. The model also allows for evaluating the oil flow rate influence on the permeability loss during the well-reservoir production curve. Sensitivity analysis investigates the parameters that highly influence the diffusivity deviation factor. Pressure and permeability input data were obtained through a uni-axial test performed in two sandstone layers of the same reservoir rock in an offshore field in Brazil. The analytical solution addressed in this paper was calibrated by a porous media oil flow simulator named IMEX®, broadly used in reservoir engineering works, and the results were accurate. The results present the instantaneous permeability decay effect by a deviation compared to the linear solution in a semi-log plot. The main advantages of the proposed solution are the accuracy, availability of a comprehensive table of the GFs, ease of implementation, and computational cost savings. It constitutes a valuable and attractive mathematical tool to calibrate new models and support well-reservoir performance management.","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":"129577929","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}
U. Sansoni, A. Waldmann, Gabriela Márcia Ribeiro Menezes, K. Gonzaga, Daniel Suchodolak, A. Martins
The reduction of the number of sections in the construction of an offshore well is a major driver for cost reduction. In order to achieve this goal, the sections must be longer, resulting in additional challenges. A critical aspect is related to the second section (no fluid return to surface) reaching high inclinations and longer extensions. Such sections are drilled with fluids with no carrying capacity, reaching 1500 m and inclinations as high as 65 degrees, resulting in expressive cuttings accumulation in the wellbore annulus. The scope of this article is to present a novel hydraulics design procedure which accounts for the effect of hole cleaning actions during well construction which reposition hydraulic parameters into acceptable criteria. This paper details novel design procedures which include the following steps: Defining cuttings bed height deposited along the wellbore annulus using traditional steady state cuttings transport models. This information is the initial condition for the design of hole cleaning pills pumping. Estimation of the extension of the cuttings bed through a material balance. Estimation of drag efforts for drillstring movement in the presence of a cuttings bed and the maximum well length which can be handled by the rig without carrying extra hole cleaning procedures. Calculation of the solids removal due to the pumping of hole cleaning pills based on a transient solid-liquid model. Optimization of the frequency, volumes and pump rates for the cleaning pills. This way, the proposed methodology allows the creation of a hydraulics design package which incorporates the optimization of hole cleaning actions during the drilling of a deviated well with fluids which do not present cuttings carrying capacity. The procedure was successfully implemented in 4 offshore wells in Campos basin, offshore Brazil, which were built in only 3 sections including a horizontal section. The present methodology is a milestone in hydraulics design for offshore wells, enabling the construction of horizontal wells in 3 phases resulting in a huge well construction time reduction.
{"title":"A Novel Hydraulics Design Approach Enables Simplified Configuration Offshore Wells","authors":"U. Sansoni, A. Waldmann, Gabriela Márcia Ribeiro Menezes, K. Gonzaga, Daniel Suchodolak, A. Martins","doi":"10.4043/32570-ms","DOIUrl":"https://doi.org/10.4043/32570-ms","url":null,"abstract":"\u0000 The reduction of the number of sections in the construction of an offshore well is a major driver for cost reduction. In order to achieve this goal, the sections must be longer, resulting in additional challenges. A critical aspect is related to the second section (no fluid return to surface) reaching high inclinations and longer extensions. Such sections are drilled with fluids with no carrying capacity, reaching 1500 m and inclinations as high as 65 degrees, resulting in expressive cuttings accumulation in the wellbore annulus. The scope of this article is to present a novel hydraulics design procedure which accounts for the effect of hole cleaning actions during well construction which reposition hydraulic parameters into acceptable criteria.\u0000 This paper details novel design procedures which include the following steps:\u0000 Defining cuttings bed height deposited along the wellbore annulus using traditional steady state cuttings transport models. This information is the initial condition for the design of hole cleaning pills pumping. Estimation of the extension of the cuttings bed through a material balance. Estimation of drag efforts for drillstring movement in the presence of a cuttings bed and the maximum well length which can be handled by the rig without carrying extra hole cleaning procedures. Calculation of the solids removal due to the pumping of hole cleaning pills based on a transient solid-liquid model. Optimization of the frequency, volumes and pump rates for the cleaning pills.\u0000 This way, the proposed methodology allows the creation of a hydraulics design package which incorporates the optimization of hole cleaning actions during the drilling of a deviated well with fluids which do not present cuttings carrying capacity. The procedure was successfully implemented in 4 offshore wells in Campos basin, offshore Brazil, which were built in only 3 sections including a horizontal section.\u0000 The present methodology is a milestone in hydraulics design for offshore wells, enabling the construction of horizontal wells in 3 phases resulting in a huge well construction time reduction.","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":"127234743","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}
Daniel Asante Otchere, A. Latiff, Mohamed Yassir Taki, L. Dafyak
More than 40 billion tonnes of CO2 are released annually, hampering climate change efforts. The goal of current research is to utilise these gases in generating energy. The oil and gas industry faces increasing expectations to clarify the implications of energy transitions for their operations and business models, reduce greenhouse gas emissions, and achieve the Paris Agreement and Glasgow Climate Pact targets. A solution is integrating machine learning and geothermal energy to optimise field development to reduce CO2 emissions while meeting energy demands. The study area is a simulated actual field data, with three existing geothermal doublets and six exploration wells. The development plan aims to satisfy the energy demand for two locations, D1 and D2, for the next 100 years, using geothermal energy and optimising field development plans via machine learning models as surrogate models. A pseudo-geological model was developed using limited field data to identify sweet spots for further drilling. Four separate model cases were simulated using DARTS. The time-energy data from DARTS was then used to train and test several machine learning models to serve as a proxy model to optimise the best strategy to meet the energy demand. The economic model was simulated for 20 years for the selected strategy for field development. Using an injection rate of 500 m3/day per well to validate the ML models, the best-performing model had a mean absolute error within the range of 0.6 to 1.5 MW for all the doublets. Based on the ML results, the computational power and time required for field development plan simulation were dramatically reduced, and several configurations were performed. The optimal strategy for this field comprises 7 geothermal doublets, 3 for D1 and 4 for D2. This strategy uses all available wells to avoid lost investment or excess cost when those wells are needed to complement production when decline sets in after 20 years, allowing a reliable and long-term energy supply. This strategy will achieve a net energy output of 108 MW for D2 and 82 for D1. This strategy uses machine learning energy estimation for the optimum configuration and addresses the issues of excess energy storage, uncertainty in production, and rising energy demand. The economic model was based on a fixed OPEX, an estimated Capex based on field development strategy, and an associated discount rate of 7%. The project resulted in a Levelized Cost of Energy of €11.16/MWH for 20 years whiles reducing annual CO2 emissions by about 367,000 metric tons. This study shows that geothermal energy is a crucial step toward cleaner energy. ML can speed up the energy transition by optimising geothermal field development. This research aims to reduce CO2 emissions while meeting energy needs.
{"title":"Machine-Learning-Based Proxy Modelling for Geothermal Field Development Optimisation","authors":"Daniel Asante Otchere, A. Latiff, Mohamed Yassir Taki, L. Dafyak","doi":"10.4043/32301-ms","DOIUrl":"https://doi.org/10.4043/32301-ms","url":null,"abstract":"\u0000 More than 40 billion tonnes of CO2 are released annually, hampering climate change efforts. The goal of current research is to utilise these gases in generating energy. The oil and gas industry faces increasing expectations to clarify the implications of energy transitions for their operations and business models, reduce greenhouse gas emissions, and achieve the Paris Agreement and Glasgow Climate Pact targets. A solution is integrating machine learning and geothermal energy to optimise field development to reduce CO2 emissions while meeting energy demands.\u0000 The study area is a simulated actual field data, with three existing geothermal doublets and six exploration wells. The development plan aims to satisfy the energy demand for two locations, D1 and D2, for the next 100 years, using geothermal energy and optimising field development plans via machine learning models as surrogate models. A pseudo-geological model was developed using limited field data to identify sweet spots for further drilling. Four separate model cases were simulated using DARTS. The time-energy data from DARTS was then used to train and test several machine learning models to serve as a proxy model to optimise the best strategy to meet the energy demand. The economic model was simulated for 20 years for the selected strategy for field development.\u0000 Using an injection rate of 500 m3/day per well to validate the ML models, the best-performing model had a mean absolute error within the range of 0.6 to 1.5 MW for all the doublets. Based on the ML results, the computational power and time required for field development plan simulation were dramatically reduced, and several configurations were performed. The optimal strategy for this field comprises 7 geothermal doublets, 3 for D1 and 4 for D2. This strategy uses all available wells to avoid lost investment or excess cost when those wells are needed to complement production when decline sets in after 20 years, allowing a reliable and long-term energy supply. This strategy will achieve a net energy output of 108 MW for D2 and 82 for D1. This strategy uses machine learning energy estimation for the optimum configuration and addresses the issues of excess energy storage, uncertainty in production, and rising energy demand. The economic model was based on a fixed OPEX, an estimated Capex based on field development strategy, and an associated discount rate of 7%. The project resulted in a Levelized Cost of Energy of €11.16/MWH for 20 years whiles reducing annual CO2 emissions by about 367,000 metric tons. This study shows that geothermal energy is a crucial step toward cleaner energy. ML can speed up the energy transition by optimising geothermal field development. This research aims to reduce CO2 emissions while meeting energy needs.","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":"129034594","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}
E. Sortica, J. Percy, Leonardo Paiva Goulart, Manuel Parcero Oliveira
Búzios is the largest ultra-deep water oil field in the world, located on the Brazilian coast, in the pre-salt polygon. Its development has taken place at an accelerated pace, with more than 60 wells already drilled and 4 FPSO's operating by the end of 2022, and a forecast of 7 more installed up to 2026, and at least 80 more wells till 2030. In this way, well configurations represent a great challenge, requiring technological and technical developments to allow high production flow and maintenance of integrity throughout the field's productive life, estimated in 30 years. Several well configurations, whether in drilling or in completion, were applied with greater or lesser success, bringing objective results in the reduction of time in well construction: from 130 days at the beginning of development to durations of less than 80 days, reducing CAPEX and increasing the rate of return on investment. This work aims to describe the various challenges faced in the design of well projects and construction, whether in drilling or completion, as well as how the geological characteristics of the field influenced the choices and methodologies adopted. In addition, demonstrate how the methodologies contributed to improve the quality of construction and linked to the reduction of time and costs.
{"title":"Buzios: The Development of Well Construction in a Giant Pre-Salt Field","authors":"E. Sortica, J. Percy, Leonardo Paiva Goulart, Manuel Parcero Oliveira","doi":"10.4043/32246-ms","DOIUrl":"https://doi.org/10.4043/32246-ms","url":null,"abstract":"\u0000 Búzios is the largest ultra-deep water oil field in the world, located on the Brazilian coast, in the pre-salt polygon. Its development has taken place at an accelerated pace, with more than 60 wells already drilled and 4 FPSO's operating by the end of 2022, and a forecast of 7 more installed up to 2026, and at least 80 more wells till 2030.\u0000 In this way, well configurations represent a great challenge, requiring technological and technical developments to allow high production flow and maintenance of integrity throughout the field's productive life, estimated in 30 years.\u0000 Several well configurations, whether in drilling or in completion, were applied with greater or lesser success, bringing objective results in the reduction of time in well construction: from 130 days at the beginning of development to durations of less than 80 days, reducing CAPEX and increasing the rate of return on investment.\u0000 This work aims to describe the various challenges faced in the design of well projects and construction, whether in drilling or completion, as well as how the geological characteristics of the field influenced the choices and methodologies adopted. In addition, demonstrate how the methodologies contributed to improve the quality of construction and linked to the reduction of time and costs.","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":"125456641","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}
F. Cutrim, C. Azevedo, Renan Martins Baptista, André Alonso Fernandes
Well Containment Analysis – WCA - is a set of integrity analysis criteria in a shut in scenario performed during the well design phase. The installation of a capping and shut in of the well shall not induce hydrocarbon leakages to the seabed. One of the integrity analysis criteria within WCA is a situation in which the well, in a blowout scenario, is closed with the capping, and a fracture is then initiated at a specific casing shoe of the well, propagating through shallow formations. The analysis ensures that the time for fracture propagation to reach the mudline is longer than the time to drill a relief well and have the well controlled. When considering a situation of a fracture propagation in a blowout scenario after capping and controlling the well there are two main possibilities: (I) a shallow reservoir can absorb the hydrocarbon flow from a deeper reservoir, (II) the time required for the fracture propagation to reach the seabed is greater than the time needed to control the well in blowout situation, guaranteeing that there is no fluid broaching to the seabed. When considering the time for fracture propagation, a safety margin is needed due to uncertainties in the geological data. This work aims to present a few case studies where well projects didn’t attend WCA analysis considering P90 pore pressure scenario and needed further analysis to ensure attendance of well integrity. In this situation, studies were done considering fracture propagation beginning after the well closure due to a hypothetic blowout, trying to analyze if hydrocarbons would broach to the mudline, and if so, how much time such an event could occur. Study results show the impact of geology and geomechanics on fracture propagation. There are situations in which the fracture remains confined due to the presence of a shallower reservoir and others where the fracture broaches to the mudline in a short amount of time. This analysis has the potential to turn the concept of well integrity more flexible, allowing the well designer to combine, in a tentative optimal way, a safe and feasible design in more challenging scenarios.
{"title":"Broachment Studies Considering Fracture Propagation in a Well Containment Analysis","authors":"F. Cutrim, C. Azevedo, Renan Martins Baptista, André Alonso Fernandes","doi":"10.4043/32271-ms","DOIUrl":"https://doi.org/10.4043/32271-ms","url":null,"abstract":"\u0000 Well Containment Analysis – WCA - is a set of integrity analysis criteria in a shut in scenario performed during the well design phase. The installation of a capping and shut in of the well shall not induce hydrocarbon leakages to the seabed. One of the integrity analysis criteria within WCA is a situation in which the well, in a blowout scenario, is closed with the capping, and a fracture is then initiated at a specific casing shoe of the well, propagating through shallow formations. The analysis ensures that the time for fracture propagation to reach the mudline is longer than the time to drill a relief well and have the well controlled.\u0000 When considering a situation of a fracture propagation in a blowout scenario after capping and controlling the well there are two main possibilities: (I) a shallow reservoir can absorb the hydrocarbon flow from a deeper reservoir, (II) the time required for the fracture propagation to reach the seabed is greater than the time needed to control the well in blowout situation, guaranteeing that there is no fluid broaching to the seabed. When considering the time for fracture propagation, a safety margin is needed due to uncertainties in the geological data.\u0000 This work aims to present a few case studies where well projects didn’t attend WCA analysis considering P90 pore pressure scenario and needed further analysis to ensure attendance of well integrity. In this situation, studies were done considering fracture propagation beginning after the well closure due to a hypothetic blowout, trying to analyze if hydrocarbons would broach to the mudline, and if so, how much time such an event could occur.\u0000 Study results show the impact of geology and geomechanics on fracture propagation. There are situations in which the fracture remains confined due to the presence of a shallower reservoir and others where the fracture broaches to the mudline in a short amount of time.\u0000 This analysis has the potential to turn the concept of well integrity more flexible, allowing the well designer to combine, in a tentative optimal way, a safe and feasible design in more challenging scenarios.","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":"125721203","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}
Jose Carlos Do Nascimento Travassos, Edmar Diniz de Figueiredo, Lourenço Lustosa Froes Silva, Leonardo Schacherl de Lima, Luiz Felipe Mathias Saramago
The ambitious five-year strategic business plan for Petrobras presented a challenge for its Surface Installation Engineering Department. This paper explores the business case behind the strategy, initiatives and identified issues that enabled Petrobras to design, plan, contract, build and deliver more than fifteen new O&G production systems. The company transformation relied on strategic parallel initiatives. Four areas concentrated the efforts: Corporate Integration, Surface Installations, Subsea Systems and Reservoir Wells. This article focuses on the analysis of the technical actions in the Surface Installation department. Nonetheless, it summarizes the related essential efforts, as well. The optimization process started with high level assumptions, for instance to reinforce one company value. That is, to keep and develop a strong in-house technical knowledge. This allowed to continue a previous development initiative to create internal Concept and Basic Design Engineering for Standard FPSO Design. The major challenge occurred during the COVID-19 pandemic. Petrobras mobilized its longest and largest Organizational Response Structure (EOR) team in its history. It involved all company departments with direct contribution of more than a thousand employees assigned for two years. With deep respect to the lives impacted and lost, there were lessons learned in this process, although Petrobras managed to continue its essential operations. From Corporate Integration perspective, Petrobras actively managed its asset portfolio to reduce the company's debt. Combined with favorable commodity prices, it allowed the company to restore and increase its financial situation to invest in oil production development despite observed volatility in the macroeconomic scenario. Regarding Reservoir and Wells, innovative technology created conditions to reduce the overall completion time. Subsea Systems layout optimizations and a more efficient resource management like the PLSV assigned fleet present significant contribution to the results. Focusing on Surface Installations, in this article are detailed the actions taken to improve the internal conditions to meet the company's strategic plan. Firstly, the reinforcement of internal capacity for Concept and Basic Design Engineering in standard FPSO Design. The portfolio of FPSOs allowed design standardization process to evolve. Optimization in system machinery design templates saved time while respecting each project unique input design conditions. One of the results was a new series of FPSOs with All Electric concept design. It consequently tends to increase efficiency and overall reduction of greenhouse gas emissions. Another key point identified was the interface among Petrobras, its supply partners, and shipyards. Through a permanent FPSO market monitoring committee, the process of procuring technical qualification was updated and stimulated early engagement of critical equipment suppliers. Furthermore, Petro
{"title":"2023-2027 Capital Project Portfolio: The Strategy and Issues Behind the Challenge to Undertake the New FPSOs Necessary to Fulfill the Company's Pre-Salt Business Plan in Brazil","authors":"Jose Carlos Do Nascimento Travassos, Edmar Diniz de Figueiredo, Lourenço Lustosa Froes Silva, Leonardo Schacherl de Lima, Luiz Felipe Mathias Saramago","doi":"10.4043/32631-ms","DOIUrl":"https://doi.org/10.4043/32631-ms","url":null,"abstract":"\u0000 The ambitious five-year strategic business plan for Petrobras presented a challenge for its Surface Installation Engineering Department. This paper explores the business case behind the strategy, initiatives and identified issues that enabled Petrobras to design, plan, contract, build and deliver more than fifteen new O&G production systems.\u0000 The company transformation relied on strategic parallel initiatives. Four areas concentrated the efforts: Corporate Integration, Surface Installations, Subsea Systems and Reservoir Wells. This article focuses on the analysis of the technical actions in the Surface Installation department. Nonetheless, it summarizes the related essential efforts, as well.\u0000 The optimization process started with high level assumptions, for instance to reinforce one company value. That is, to keep and develop a strong in-house technical knowledge. This allowed to continue a previous development initiative to create internal Concept and Basic Design Engineering for Standard FPSO Design.\u0000 The major challenge occurred during the COVID-19 pandemic. Petrobras mobilized its longest and largest Organizational Response Structure (EOR) team in its history. It involved all company departments with direct contribution of more than a thousand employees assigned for two years. With deep respect to the lives impacted and lost, there were lessons learned in this process, although Petrobras managed to continue its essential operations.\u0000 From Corporate Integration perspective, Petrobras actively managed its asset portfolio to reduce the company's debt. Combined with favorable commodity prices, it allowed the company to restore and increase its financial situation to invest in oil production development despite observed volatility in the macroeconomic scenario.\u0000 Regarding Reservoir and Wells, innovative technology created conditions to reduce the overall completion time. Subsea Systems layout optimizations and a more efficient resource management like the PLSV assigned fleet present significant contribution to the results.\u0000 Focusing on Surface Installations, in this article are detailed the actions taken to improve the internal conditions to meet the company's strategic plan. Firstly, the reinforcement of internal capacity for Concept and Basic Design Engineering in standard FPSO Design. The portfolio of FPSOs allowed design standardization process to evolve. Optimization in system machinery design templates saved time while respecting each project unique input design conditions. One of the results was a new series of FPSOs with All Electric concept design. It consequently tends to increase efficiency and overall reduction of greenhouse gas emissions. Another key point identified was the interface among Petrobras, its supply partners, and shipyards. Through a permanent FPSO market monitoring committee, the process of procuring technical qualification was updated and stimulated early engagement of critical equipment suppliers. Furthermore, Petro","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":"131213563","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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