Currently, low oil prices pose a challenge to the financial state of the industry. Therefore, it is very important that companies optimize costs while maintaining or even increasing oil production. At the same time, with oil production declining due high water cuts and facility volume limitations in an offshore production system, it is necessary to look for solutions in order to maintain economic viability by increasing oil recovery in mature reservoirs. Among some alternatives, the subsea separator represents a good prospect for dealing with these challenges. This paper aims to describe a methodology to perform the technical feasibility study of deploying an Oil/Water Subsea Separator in Brazilian Offshore Field. The technical results were then used as part of an economic analysis which is outside the scope of the present paper. The study is comprised four wells that are linked to the manifold and the subsea separator. In the subsea separator, 70% of the produced water is separated and reinjected in a disposal well. Hence, the fluids which remains (oil, gas and 30% of water) flows up to the platform. Since this reinjected water volume is not flowing to the platform anymore, more fluid can be processed, allowing the wells to operate on larger potentials resulting in an increased cumulative oil production to the field. Computational simulation approach was followed by using the pore flow simulation, flow assurance simulation and a coupler that integrates both of these.
{"title":"Methodology to a Feasibility Study to Implement an Oil/Water Subsea Separation","authors":"Guilherme Cosme Viganô","doi":"10.4043/29895-ms","DOIUrl":"https://doi.org/10.4043/29895-ms","url":null,"abstract":"\u0000 Currently, low oil prices pose a challenge to the financial state of the industry. Therefore, it is very important that companies optimize costs while maintaining or even increasing oil production. At the same time, with oil production declining due high water cuts and facility volume limitations in an offshore production system, it is necessary to look for solutions in order to maintain economic viability by increasing oil recovery in mature reservoirs. Among some alternatives, the subsea separator represents a good prospect for dealing with these challenges.\u0000 This paper aims to describe a methodology to perform the technical feasibility study of deploying an Oil/Water Subsea Separator in Brazilian Offshore Field. The technical results were then used as part of an economic analysis which is outside the scope of the present paper.\u0000 The study is comprised four wells that are linked to the manifold and the subsea separator. In the subsea separator, 70% of the produced water is separated and reinjected in a disposal well. Hence, the fluids which remains (oil, gas and 30% of water) flows up to the platform. Since this reinjected water volume is not flowing to the platform anymore, more fluid can be processed, allowing the wells to operate on larger potentials resulting in an increased cumulative oil production to the field. Computational simulation approach was followed by using the pore flow simulation, flow assurance simulation and a coupler that integrates both of these.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89296465","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}
We introduce a new digital rocks-based method for interpreting NMR T2 distributions in well log data acquired in vuggy deep-water carbonate reservoirs. Our method accounts for adverse borehole conditions such as mud invasion and large washouts in vuggy zones, usually neglected in conventional interpretation procedures of NMR logs. The new approach is based on describing the measured distribution of transverse relaxation times as the superposition of a finite set of log-normal components. Each component accounts for specific relaxation rates for drilling mud and original formation fluids. We carefully design our NMR interpretation model after processing whole core X-ray computed tomography (CT) images acquired in whole core samples. Estimation of density and atomic number from dual-energy CT data enabled to directly probe fluid content in the vuggy space, while image segmentation targeting the vuggy space allowed to estimate vuggy porosity and flow properties inside the vug network. Our model was able to explain correlated anomalies shown by caliper, photoelectric, and NMR T2 logarithmic mean logs for the vuggy regions in the dataset studied. The decomposition of inverted NMR T2 distributions in a set of basis functions naturally handles the uncertainty related to inversion parameters, making the task of calculating fluid concentrations and permeability indices more robust with respect to small variations in cutoff values. Permeabilities in vuggy zones estimated from NMR logs using this new method are more accurate than those rendered by conventional techniques based on T2 cutoffs or logarithmic averages, without the need to artificially introduce new fitting parameters. Using this approach, we can also explicitly quantify vuggy porosity, which is in good agreement with values obtained from segmented whole core tomographic images for this particular dataset. The combined use of the above interpretation methods confirms the value of digital rock techniques to improve the evaluation of well logs acquired in complex carbonate formations, specifically in the calculation of permeability across vuggy depth segments. Results can be used to improve well log interpretation in wells devoid of core data and/or high-resolution borehole images.
{"title":"Improved Digital Rocks-Based Model for NMR Permeability Estimation in Vuggy Deepwater Carbonates","authors":"R. Victor, C. Torres‐Verdín, M. Prodanović","doi":"10.4043/29731-ms","DOIUrl":"https://doi.org/10.4043/29731-ms","url":null,"abstract":"\u0000 We introduce a new digital rocks-based method for interpreting NMR T2 distributions in well log data acquired in vuggy deep-water carbonate reservoirs. Our method accounts for adverse borehole conditions such as mud invasion and large washouts in vuggy zones, usually neglected in conventional interpretation procedures of NMR logs.\u0000 The new approach is based on describing the measured distribution of transverse relaxation times as the superposition of a finite set of log-normal components. Each component accounts for specific relaxation rates for drilling mud and original formation fluids. We carefully design our NMR interpretation model after processing whole core X-ray computed tomography (CT) images acquired in whole core samples. Estimation of density and atomic number from dual-energy CT data enabled to directly probe fluid content in the vuggy space, while image segmentation targeting the vuggy space allowed to estimate vuggy porosity and flow properties inside the vug network.\u0000 Our model was able to explain correlated anomalies shown by caliper, photoelectric, and NMR T2 logarithmic mean logs for the vuggy regions in the dataset studied. The decomposition of inverted NMR T2 distributions in a set of basis functions naturally handles the uncertainty related to inversion parameters, making the task of calculating fluid concentrations and permeability indices more robust with respect to small variations in cutoff values. Permeabilities in vuggy zones estimated from NMR logs using this new method are more accurate than those rendered by conventional techniques based on T2 cutoffs or logarithmic averages, without the need to artificially introduce new fitting parameters. Using this approach, we can also explicitly quantify vuggy porosity, which is in good agreement with values obtained from segmented whole core tomographic images for this particular dataset.\u0000 The combined use of the above interpretation methods confirms the value of digital rock techniques to improve the evaluation of well logs acquired in complex carbonate formations, specifically in the calculation of permeability across vuggy depth segments. Results can be used to improve well log interpretation in wells devoid of core data and/or high-resolution borehole images.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75232929","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. B. Vadinal, Stephan R. Perrout, Rodrigo De Campos Chuvas, Adriano Gouveia Lima Gomes dos Passos, Leonardo Pacheco da Silva
This work presents the lessons learned from the studies carried out to understand the non-fulfillment of the hydraulic isolation required during the liner 10 ¾" cement job. Analyzing the drilling parameters performed and the events of cementing, it is possible that the stationary solids bed and the consequent poor conditioning of the well were probably responsibles for the failure to obtain the hydraulic isolation required for the cementing operation. The investigation report recommends some good practices for avoiding and/or removing the cuttings-bed. The results of some simulations carried out during the investigation studies showed that drillpipe rotation speed contributes significantly to reduce the cuttings-bed height. Additionally to the extended reach, the well studied is a design well, has a complex trajectory, and the computer simulations revealed that ROP control is mandatory to obtain a proper hole cleaning and well conditioning. It was identified that the reduction of the hole diameter has a huge impact on well conditioning, drilling fluid displacement and cement slurry displacement. At last, the paper presents some recommendations for backreaming, mainly for evaluation of ideal operational parameters; adjust the drilling rates according to the hydraulic simulation, to ensure the hole cleaning and optimize the total time of the drilling intervention.
{"title":"Influence of Hole Cleaning on the Liner Cement Job in Papa Terra Field","authors":"R. B. Vadinal, Stephan R. Perrout, Rodrigo De Campos Chuvas, Adriano Gouveia Lima Gomes dos Passos, Leonardo Pacheco da Silva","doi":"10.4043/29786-ms","DOIUrl":"https://doi.org/10.4043/29786-ms","url":null,"abstract":"\u0000 This work presents the lessons learned from the studies carried out to understand the non-fulfillment of the hydraulic isolation required during the liner 10 ¾\" cement job. Analyzing the drilling parameters performed and the events of cementing, it is possible that the stationary solids bed and the consequent poor conditioning of the well were probably responsibles for the failure to obtain the hydraulic isolation required for the cementing operation. The investigation report recommends some good practices for avoiding and/or removing the cuttings-bed. The results of some simulations carried out during the investigation studies showed that drillpipe rotation speed contributes significantly to reduce the cuttings-bed height. Additionally to the extended reach, the well studied is a design well, has a complex trajectory, and the computer simulations revealed that ROP control is mandatory to obtain a proper hole cleaning and well conditioning. It was identified that the reduction of the hole diameter has a huge impact on well conditioning, drilling fluid displacement and cement slurry displacement. At last, the paper presents some recommendations for backreaming, mainly for evaluation of ideal operational parameters; adjust the drilling rates according to the hydraulic simulation, to ensure the hole cleaning and optimize the total time of the drilling intervention.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"39 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73398494","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. Delgado, Pedro Henrique Neves Goncalves, Magda Maria de Regina Chambriard
The magnitude of the pre-salt projects, most located in Brazil ultra-deep waters, coupled with the enormous potential already auctioned, leads to the following questions: what will be Brazil's share in the world's deep-water development? How should suppliers prepare themselves to assist Brazil in the task of making these opportunities viable? Since 2013, the country awarded over R$ 43 billion in signing bonuses. Despite the pessimism associated to the oil price drop in 2014, Brazil has gone forward with the development of pre-salt areas and the resume of the bidding rounds, reaching the top 10th position in world's biggest oil producers (BP 2019). This paper forecasts the oil potential for these areas, as well as the Brazilian oil production for the next 15 years and the demand for facilities to reach that potential. Those forecasts clarify the increasing importance of Brazilian deep-water oil in the global scenario.
{"title":"Brazil Oil and Gas Sector Piece De Resistance: The Pre-Salt Play Developments","authors":"F. Delgado, Pedro Henrique Neves Goncalves, Magda Maria de Regina Chambriard","doi":"10.4043/29840-ms","DOIUrl":"https://doi.org/10.4043/29840-ms","url":null,"abstract":"\u0000 The magnitude of the pre-salt projects, most located in Brazil ultra-deep waters, coupled with the enormous potential already auctioned, leads to the following questions: what will be Brazil's share in the world's deep-water development? How should suppliers prepare themselves to assist Brazil in the task of making these opportunities viable?\u0000 Since 2013, the country awarded over R$ 43 billion in signing bonuses. Despite the pessimism associated to the oil price drop in 2014, Brazil has gone forward with the development of pre-salt areas and the resume of the bidding rounds, reaching the top 10th position in world's biggest oil producers (BP 2019).\u0000 This paper forecasts the oil potential for these areas, as well as the Brazilian oil production for the next 15 years and the demand for facilities to reach that potential. Those forecasts clarify the increasing importance of Brazilian deep-water oil in the global scenario.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"18 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77347622","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}
While we are currently seeing less fires, statistically, if you do have a fire in your home, you are more likely to die today than you were 20 years ago. Add to that, that every 24 seconds, a U.S. fire department responds to a fire somewhere in the country. Nationwide, a civilian died in a fire every 2 hours and 34 minutes. (From the 2017 U.S. Fire Loss Report) The reality is, we do have many of the tools to prevent damaging fires – sprinklers, smoke alarms, codes and enforcement – but they are met with resistance from everyone from policymakers and enforcers to builders and the public. Over the years we've underused, ignored or allowed codes and safety standards to become outdated.
{"title":"Increasing Fire Safety – Fire and Life Safety Ecosystem","authors":"Anderson Queiroz Candido","doi":"10.4043/29961-ms","DOIUrl":"https://doi.org/10.4043/29961-ms","url":null,"abstract":"While we are currently seeing less fires, statistically, if you do have a fire in your home, you are more likely to die today than you were 20 years ago. Add to that, that every 24 seconds, a U.S. fire department responds to a fire somewhere in the country. Nationwide, a civilian died in a fire every 2 hours and 34 minutes. (From the 2017 U.S. Fire Loss Report)\u0000 The reality is, we do have many of the tools to prevent damaging fires – sprinklers, smoke alarms, codes and enforcement – but they are met with resistance from everyone from policymakers and enforcers to builders and the public. Over the years we've underused, ignored or allowed codes and safety standards to become outdated.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"28 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87946275","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}
A. Oshiro, R. Mendes, G. Diederichs, Dalisson Santos Vieira, Acacio Sarnaglia Do Amaral
The Restriction Diagram is a tool that delimits the minimum distance between a dynamic positioning (DP) drilling rig and surface or subsea obstacles (Platforms, anchor lines, subsea equipment) for safe operation. These diagrams are used for risk analysis and well operations restricting the operation of some rigs in some locations or avoiding very large drilling operations next to each other. They are also used as one of the parameters to determine the best position of the platform in relation to the wells, impacting any subsea layout of a new field development. The analysis of restriction diagrams are essential for risk assessment involving drilling rigs. It is important to improve the quality and robustness of the methodology presented due to safety distances. This proposal of the new model of the Restriction Diagram aims to support the risk analysis of Drilling Rigs operations including the probability of drilling rigs failure, recovery times and hydrodynamic probabilistic modeling. There is integration between all the parameters involved in the process and the propagation of its uncertainties. The reliability analysis of the dynamic positioning drilling rigs used an extensive database of incident logs, from which was extracted the occurrences of total loss of propulsive capacity of the drilling rigs that resulted in a drift-off. It was considered the operating time and failures that have occurred since 2010, as well as the drilling rig recovery time. The drift-off analysis are represented by means of hydrodynamic modeling coupled to a probabilistic simulator. This risk-based analysis from reliability and environmental conditions will give the chance of collision with obstacles for drilling operations or well intervention. This paper presents a risk assessment approach according to the new emphases that are beginning to be considered by regulatory authorities such as the Petroleum Safety Authority (PSA) in Norway, considering the integration between decision processes and uncertainty analysis.
{"title":"Restriction Diagram: Realibility Study of Drilling Ships with Dynamic Positioning System","authors":"A. Oshiro, R. Mendes, G. Diederichs, Dalisson Santos Vieira, Acacio Sarnaglia Do Amaral","doi":"10.4043/29684-ms","DOIUrl":"https://doi.org/10.4043/29684-ms","url":null,"abstract":"\u0000 The Restriction Diagram is a tool that delimits the minimum distance between a dynamic positioning (DP) drilling rig and surface or subsea obstacles (Platforms, anchor lines, subsea equipment) for safe operation. These diagrams are used for risk analysis and well operations restricting the operation of some rigs in some locations or avoiding very large drilling operations next to each other. They are also used as one of the parameters to determine the best position of the platform in relation to the wells, impacting any subsea layout of a new field development. The analysis of restriction diagrams are essential for risk assessment involving drilling rigs. It is important to improve the quality and robustness of the methodology presented due to safety distances. This proposal of the new model of the Restriction Diagram aims to support the risk analysis of Drilling Rigs operations including the probability of drilling rigs failure, recovery times and hydrodynamic probabilistic modeling. There is integration between all the parameters involved in the process and the propagation of its uncertainties.\u0000 The reliability analysis of the dynamic positioning drilling rigs used an extensive database of incident logs, from which was extracted the occurrences of total loss of propulsive capacity of the drilling rigs that resulted in a drift-off. It was considered the operating time and failures that have occurred since 2010, as well as the drilling rig recovery time. The drift-off analysis are represented by means of hydrodynamic modeling coupled to a probabilistic simulator. This risk-based analysis from reliability and environmental conditions will give the chance of collision with obstacles for drilling operations or well intervention.\u0000 This paper presents a risk assessment approach according to the new emphases that are beginning to be considered by regulatory authorities such as the Petroleum Safety Authority (PSA) in Norway, considering the integration between decision processes and uncertainty analysis.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"49 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82636893","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}
Erna Kakadjian, April Shi, J. Porter, Prahlad Yadav, D. Clapper, W. Pessanha
One of the biggest challenges when drilling in deep water is the excessive dependence of drilling fluid rheological properties on temperature. Conventional drilling fluids often have high viscosity at the seabed temperature, which increases the Equivalent Circulating Density (ECD) and surge pressures when running pipe or initiating circulation, elevating the risk of fracturing the wellbore. This paper describes the development of a drilling fluid for deep-water applications, with minimum viscosity variation with temperature. Multiple laboratory formulations were evaluated during the development of the new, non-aqueous based drilling fluid that meets deep-water's challenging rheological and barite suspension requirements. CaCl2 brine was used as the internal emulsion phase, and synthetic isomerized olefin as the base oil. The testing followed the API Recommended Practice for Field Testing Oil-based Drilling Fluids. Samples were aged at dynamic conditions for 16 hours at several temperatures. Then, rheological properties and high-pressure high-temperature (HPHT) fluid loss, emulsion stability, and dynamic sagging were tested. Static sag experiments were also carried out for up to seven days together with improved step down rheology tests. A low-impact, non-aqueous drilling fluid (LIDF) was designed to minimize ECD increases by reducing the effect of cold temperature on the fluid viscosity. The fluid offers a superior low viscosity profile and rapid-set, easy-break gel strengths, while maintaining low shear rate viscosity at high temperatures with optimal weight material suspension. The fluid is also compatible with all contaminants usually found during the drilling operation and meets all the regulatory requirements for the Gulf of Mexico and other deep-water operational areas. Field application demonstrated that LIDF reduced the effect of temperature on the fluid rheological properties and minimized the risk of induced formation losses. These same rheological features reduced non-productive time associated with cement displacement and barite sagging. Supporting laboratory and field data are presented to demonstrate the superior performance of the fluid in maintaining rheological and barite suspension properties over a wide range of temperatures. The properties of the LIDF are achieved by matching the effects of emulsifier, organophilic clay, and rheological modifiers to maintain correct rheological properties at low and high temperatures.
{"title":"Low Impact Drilling Fluid for Deepwater Drilling Frontier","authors":"Erna Kakadjian, April Shi, J. Porter, Prahlad Yadav, D. Clapper, W. Pessanha","doi":"10.4043/29802-ms","DOIUrl":"https://doi.org/10.4043/29802-ms","url":null,"abstract":"\u0000 One of the biggest challenges when drilling in deep water is the excessive dependence of drilling fluid rheological properties on temperature. Conventional drilling fluids often have high viscosity at the seabed temperature, which increases the Equivalent Circulating Density (ECD) and surge pressures when running pipe or initiating circulation, elevating the risk of fracturing the wellbore. This paper describes the development of a drilling fluid for deep-water applications, with minimum viscosity variation with temperature.\u0000 Multiple laboratory formulations were evaluated during the development of the new, non-aqueous based drilling fluid that meets deep-water's challenging rheological and barite suspension requirements. CaCl2 brine was used as the internal emulsion phase, and synthetic isomerized olefin as the base oil. The testing followed the API Recommended Practice for Field Testing Oil-based Drilling Fluids. Samples were aged at dynamic conditions for 16 hours at several temperatures. Then, rheological properties and high-pressure high-temperature (HPHT) fluid loss, emulsion stability, and dynamic sagging were tested. Static sag experiments were also carried out for up to seven days together with improved step down rheology tests.\u0000 A low-impact, non-aqueous drilling fluid (LIDF) was designed to minimize ECD increases by reducing the effect of cold temperature on the fluid viscosity. The fluid offers a superior low viscosity profile and rapid-set, easy-break gel strengths, while maintaining low shear rate viscosity at high temperatures with optimal weight material suspension. The fluid is also compatible with all contaminants usually found during the drilling operation and meets all the regulatory requirements for the Gulf of Mexico and other deep-water operational areas. Field application demonstrated that LIDF reduced the effect of temperature on the fluid rheological properties and minimized the risk of induced formation losses. These same rheological features reduced non-productive time associated with cement displacement and barite sagging.\u0000 Supporting laboratory and field data are presented to demonstrate the superior performance of the fluid in maintaining rheological and barite suspension properties over a wide range of temperatures. The properties of the LIDF are achieved by matching the effects of emulsifier, organophilic clay, and rheological modifiers to maintain correct rheological properties at low and high temperatures.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"20 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81944743","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}
we propose a methodology based on document embedding techniques for applying Technology Intelligence Analysis in Oil and Gas (O&G) domain. We build a specialized corpus in O&G domain and train a Vector Space Model (VSM) to represent each document as a vector, in such a way that the distance between two vectors captures their semantic similarity. We explore different analysis on this VSM to infer relations between documents, in order to obtain new insights in a strategic context. this proposed methodology is based on Natural Language Processing (NLP) techniques to obtain strategic insights in a technology intelligence analysis scenario. It consists on generating a vector space model (VSM) induced from a domain-specific Oil and Gas corpus, composed of thousands of scientific articles collected from the Elsevier online database. We explore an approach to represent different entities - such as articles, authors and keywords - in the same vector space, making it possible to correlate them and infer relations of similarity based on their cosine distance. An evaluation metric is also provided in order to assist the training process and hyperparameters optimization. Oil and Gas highly technical vocabulary represents a challenge to NLP applications, in which some terms may assume a completely different meaning from the general - context domain. In this scenario, gathering an Oil and Gas corpus and training specialized vector space models for this specific domain allows increasing the quality in Technology Intelligence Analysis. The most significant finding is that we were able to explicit the semantic relationships between different entities of interest in the same VSM, also linking these relationships together with some additional metadata. An interesting application is to compare the publications of authors affiliated to two or more O&G companies at a given time. These non-trivial correlations are important to gain strategic insights considering a Technology Intelligence Analysis scenario. the novelty of this proposed methodology is the possibility of exploring new insights when correlating different entities in a technology intelligence scenario for the Oil and Gas domain, using a simple yet efficient approach based on document embedding techniques. This method applies some advanced NLP techniques to quickly process more than a hundred thousand documents in a few seconds, without requiring complex hardware resources, which would be impractical using traditional techniques.
{"title":"Technology Intelligence Analysis Based on Document Embedding Techniques for Oil and Gas Domain","authors":"Fábio Corrêa Cordeiro, Diogo da Silva Magalhães Gomes, Flávio Antônio Machado Gomes, Renata Cristina Texeira","doi":"10.4043/29707-ms","DOIUrl":"https://doi.org/10.4043/29707-ms","url":null,"abstract":"\u0000 \u0000 \u0000 we propose a methodology based on document embedding techniques for applying Technology Intelligence Analysis in Oil and Gas (O&G) domain. We build a specialized corpus in O&G domain and train a Vector Space Model (VSM) to represent each document as a vector, in such a way that the distance between two vectors captures their semantic similarity. We explore different analysis on this VSM to infer relations between documents, in order to obtain new insights in a strategic context.\u0000 \u0000 \u0000 \u0000 this proposed methodology is based on Natural Language Processing (NLP) techniques to obtain strategic insights in a technology intelligence analysis scenario. It consists on generating a vector space model (VSM) induced from a domain-specific Oil and Gas corpus, composed of thousands of scientific articles collected from the Elsevier online database. We explore an approach to represent different entities - such as articles, authors and keywords - in the same vector space, making it possible to correlate them and infer relations of similarity based on their cosine distance. An evaluation metric is also provided in order to assist the training process and hyperparameters optimization.\u0000 \u0000 \u0000 \u0000 Oil and Gas highly technical vocabulary represents a challenge to NLP applications, in which some terms may assume a completely different meaning from the general - context domain. In this scenario, gathering an Oil and Gas corpus and training specialized vector space models for this specific domain allows increasing the quality in Technology Intelligence Analysis. The most significant finding is that we were able to explicit the semantic relationships between different entities of interest in the same VSM, also linking these relationships together with some additional metadata. An interesting application is to compare the publications of authors affiliated to two or more O&G companies at a given time. These non-trivial correlations are important to gain strategic insights considering a Technology Intelligence Analysis scenario.\u0000 \u0000 \u0000 \u0000 the novelty of this proposed methodology is the possibility of exploring new insights when correlating different entities in a technology intelligence scenario for the Oil and Gas domain, using a simple yet efficient approach based on document embedding techniques. This method applies some advanced NLP techniques to quickly process more than a hundred thousand documents in a few seconds, without requiring complex hardware resources, which would be impractical using traditional techniques.\u0000","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77940727","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. Bustos, Diana Chaparro, David Alfonso Serrano, Alvaro Chapellin, E. Kovarskiy, Diego Fernando Rodriguez, Heliodoro Cañarete, Juan Carlos Ortiz
Several fields in Colombia are in the maturity phase. While the efforts are mainly focused on workflows and technology incorporation for either increasing hydrocarbon production and/or minimizing water cut, the combination of variable salinities due to production/waterflood with complex mineralogies and shales distributions, is detrimental to a proper saturation assessment with archie methods. The content of clay, thin laminations and small pore sizes add to the rock an important conductivity component that translates into low resistivity responses when measuring with low frequency conductivity devices (either based on induction or laterolog principles) and low contrast between sand and shales. Such formation evaluation issues are detrimental to achieve representative hydrocarbon saturation computations in many interest zones in this case study. In this context, we propose a formation evaluation solution based on wireline dielectric dispersion measurements. Using a 1-inch vertical resolution wireline-conveyed device, we polarize the reservoirs with a multi-frequency electromagnetic field and evaluate the formation response to the application of this field. At higher frequencies, the electronic polarization phenomena enable to displace cloud of atoms in the formation where information on low dielectric constant materials (hydrocarbons, matrix) is assessed. At intermediate frequencies, the molecular polarization occurs by rotating-reorienting the dipoles (water molecules) creating a strong attenuation and phase shift of the electromagnetic field; consequently, allowing to measure salinity and resistivity-independent water volume. Lastly, at lower frequencies the predominance of Maxwell-Wagner effects which are related to the electrical charge redistribution at interfaces due to electromagnetic field application, enable to obtain information on rock textural information (tortuosity and cation exchange capacity). By building a petrophysical model with dielectric dispersion and nuclear logs, we then obtain a high-resolution resistivity and salinity-independent formation evaluation that solves for porosity and water vs oil saturation with a single and fast wireline logging run.
{"title":"Finding New Hydrocarbons in Mature Fields with High Resolution Dielectric Dispersion","authors":"U. Bustos, Diana Chaparro, David Alfonso Serrano, Alvaro Chapellin, E. Kovarskiy, Diego Fernando Rodriguez, Heliodoro Cañarete, Juan Carlos Ortiz","doi":"10.4043/29896-ms","DOIUrl":"https://doi.org/10.4043/29896-ms","url":null,"abstract":"\u0000 Several fields in Colombia are in the maturity phase. While the efforts are mainly focused on workflows and technology incorporation for either increasing hydrocarbon production and/or minimizing water cut, the combination of variable salinities due to production/waterflood with complex mineralogies and shales distributions, is detrimental to a proper saturation assessment with archie methods. The content of clay, thin laminations and small pore sizes add to the rock an important conductivity component that translates into low resistivity responses when measuring with low frequency conductivity devices (either based on induction or laterolog principles) and low contrast between sand and shales. Such formation evaluation issues are detrimental to achieve representative hydrocarbon saturation computations in many interest zones in this case study.\u0000 In this context, we propose a formation evaluation solution based on wireline dielectric dispersion measurements. Using a 1-inch vertical resolution wireline-conveyed device, we polarize the reservoirs with a multi-frequency electromagnetic field and evaluate the formation response to the application of this field. At higher frequencies, the electronic polarization phenomena enable to displace cloud of atoms in the formation where information on low dielectric constant materials (hydrocarbons, matrix) is assessed. At intermediate frequencies, the molecular polarization occurs by rotating-reorienting the dipoles (water molecules) creating a strong attenuation and phase shift of the electromagnetic field; consequently, allowing to measure salinity and resistivity-independent water volume. Lastly, at lower frequencies the predominance of Maxwell-Wagner effects which are related to the electrical charge redistribution at interfaces due to electromagnetic field application, enable to obtain information on rock textural information (tortuosity and cation exchange capacity). By building a petrophysical model with dielectric dispersion and nuclear logs, we then obtain a high-resolution resistivity and salinity-independent formation evaluation that solves for porosity and water vs oil saturation with a single and fast wireline logging run.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83363550","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}
Liang Sun, Liang Wei, Hang Zhao, Baozhu Li, Yong Li
Carbonate reservoirs in the Middle East are characterized by strong heterogeneity, fairly subtle barriers and baffles, which result in low water flood swept volume and poor displacement efficiency. Therefore, optimum well pattern deployment is critical for high-efficiency development of such reservoirs. This paper focuses on a giant carbonate reservoir and discusses the application of highly inclined well to optimizing the deployment of well pattern. In this paper, first, based on the productivity formulae of slanted and horizontal wells proposed by Besson, the adaptability of highly inclined well in giant carbonate reservoir was evaluated. Then, the well design parameters were optimized by using numerical simulation. Finally, the optimum well pattern of "water injection in vertical well and oil production in highly inclined well" was established, and sound development strategies were determined. This provided us the foundation to propose customized water flooding plan. The successful application of this development scheme for M carbonate reservoir in Iraq validated the technical feasibility, which achieved considerable economic benefits. The results indicate that highly inclined well has advantages in productivity and adaptability of well type to this kind of reservoirs. The production of top low-permeability layers and bottom low-permeability layers in M reservoir with inclined interval and horizontal interval respectively makes full use of highly inclined well, which balances injectivity and productivity of different reservoir properties. The proper length of highly inclined well is 2953∼3281 feet, and the ratio of inclined interval to horizontal interval is about 2. The optimized well pattern of "water injection in vertical well and oil production in highly inclined well" improves water injection sweep efficiency and recovery factor. The M reservoir in Iraq has achieved an annual yield of more than 1.5 million barrels. The water injection development for large-scale carbonate reservoirs in the Middle East is still at exploration stage and lack of mature experience. The proposed development pattern in this paper provides a methodology for the efficient development of similar reservoirs.
{"title":"Application of Highly Inclined Well to Optimizing Well Pattern: Case Study of a Giant Carbonate Reservoir in the Middle East","authors":"Liang Sun, Liang Wei, Hang Zhao, Baozhu Li, Yong Li","doi":"10.4043/29942-ms","DOIUrl":"https://doi.org/10.4043/29942-ms","url":null,"abstract":"\u0000 Carbonate reservoirs in the Middle East are characterized by strong heterogeneity, fairly subtle barriers and baffles, which result in low water flood swept volume and poor displacement efficiency. Therefore, optimum well pattern deployment is critical for high-efficiency development of such reservoirs. This paper focuses on a giant carbonate reservoir and discusses the application of highly inclined well to optimizing the deployment of well pattern.\u0000 In this paper, first, based on the productivity formulae of slanted and horizontal wells proposed by Besson, the adaptability of highly inclined well in giant carbonate reservoir was evaluated. Then, the well design parameters were optimized by using numerical simulation. Finally, the optimum well pattern of \"water injection in vertical well and oil production in highly inclined well\" was established, and sound development strategies were determined. This provided us the foundation to propose customized water flooding plan. The successful application of this development scheme for M carbonate reservoir in Iraq validated the technical feasibility, which achieved considerable economic benefits.\u0000 The results indicate that highly inclined well has advantages in productivity and adaptability of well type to this kind of reservoirs. The production of top low-permeability layers and bottom low-permeability layers in M reservoir with inclined interval and horizontal interval respectively makes full use of highly inclined well, which balances injectivity and productivity of different reservoir properties. The proper length of highly inclined well is 2953∼3281 feet, and the ratio of inclined interval to horizontal interval is about 2. The optimized well pattern of \"water injection in vertical well and oil production in highly inclined well\" improves water injection sweep efficiency and recovery factor. The M reservoir in Iraq has achieved an annual yield of more than 1.5 million barrels.\u0000 The water injection development for large-scale carbonate reservoirs in the Middle East is still at exploration stage and lack of mature experience. The proposed development pattern in this paper provides a methodology for the efficient development of similar reservoirs.","PeriodicalId":11089,"journal":{"name":"Day 2 Wed, October 30, 2019","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-10-28","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88770795","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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