The paper is continuation of our previous work published in the SPE-192896. This work illustrates horizontal well placement sensitivity analysis that was conducted on a complex Valanginian (Cretaceous) unsaturated oil carbonate reservoir with strong water drive. Existing producer wells are 80% horizontal and the remaining 20% are vertical to deviated producers. The production history is the approximately 20 years and currently a peripheral water injection is implemented, all injector wells are horizontals. The well placement is very challenging due to the presence of some thin high permeability streaks intervals with permeability value of up to 1 Darcy. Early water breakthrough encountered in the existing oil producers is a serious problem which results in lower recovery factor and costly lifting treatment. In addition, premature breakthrough would leave behind the potential oil accumulation. Therefore defining the optimum placement location of the producers is a crucial decision to be decided during well plan and field development. In this paper we applied novel approach for stochastically modeling complex carbonate reservoir lithofacies and properties distribution using a pre-defined High Resolution Sequence Stratigraphy (HRSS) model subzonation. The key static geological elements that must be well defined are HRSS framework, lithofacies architecture, and field wide rock properties. In this study, we apply integrated geosciences, geostatistical, and flow simulations to assess options for well placement. This new holistic approach has recently been successfully implemented in the studied field. The resulted geostatistical model was able to explain pressure depletion and production rate as shown in historical production data of the field. The resulting dynamic model will hence provide reliable production forecast and reservoirs development plan which will eventually allow accomplishing the mandate recovery target. Flow simulation was used to analyze the performance of the well considering horizontal the well azimuth, well inclination, wells length, wells position relative to the sequence stratigraphic zonation, and well position relative to the water contact. In addition, multi-scenarios of well placement were created to see the impact on the oil rate, plateau, and water breakthrough time. Some producers in the studied reservoirs have been drilled using the multidiscipline study recommendation. Actual property and rate derived from the newly drilled wells displayed a very reasonable match to the expected property from the model.
{"title":"Well Placement Assessment Using Sequence Stratigraphic Zonation in a Complex Carbonate Reservoir","authors":"A. Salahuddin, K. Khan, R. A. Ali, K. Hammadi","doi":"10.2118/193057-MS","DOIUrl":"https://doi.org/10.2118/193057-MS","url":null,"abstract":"\u0000 The paper is continuation of our previous work published in the SPE-192896. This work illustrates horizontal well placement sensitivity analysis that was conducted on a complex Valanginian (Cretaceous) unsaturated oil carbonate reservoir with strong water drive. Existing producer wells are 80% horizontal and the remaining 20% are vertical to deviated producers. The production history is the approximately 20 years and currently a peripheral water injection is implemented, all injector wells are horizontals. The well placement is very challenging due to the presence of some thin high permeability streaks intervals with permeability value of up to 1 Darcy. Early water breakthrough encountered in the existing oil producers is a serious problem which results in lower recovery factor and costly lifting treatment. In addition, premature breakthrough would leave behind the potential oil accumulation. Therefore defining the optimum placement location of the producers is a crucial decision to be decided during well plan and field development.\u0000 In this paper we applied novel approach for stochastically modeling complex carbonate reservoir lithofacies and properties distribution using a pre-defined High Resolution Sequence Stratigraphy (HRSS) model subzonation. The key static geological elements that must be well defined are HRSS framework, lithofacies architecture, and field wide rock properties. In this study, we apply integrated geosciences, geostatistical, and flow simulations to assess options for well placement.\u0000 This new holistic approach has recently been successfully implemented in the studied field. The resulted geostatistical model was able to explain pressure depletion and production rate as shown in historical production data of the field. The resulting dynamic model will hence provide reliable production forecast and reservoirs development plan which will eventually allow accomplishing the mandate recovery target.\u0000 Flow simulation was used to analyze the performance of the well considering horizontal the well azimuth, well inclination, wells length, wells position relative to the sequence stratigraphic zonation, and well position relative to the water contact. In addition, multi-scenarios of well placement were created to see the impact on the oil rate, plateau, and water breakthrough time. Some producers in the studied reservoirs have been drilled using the multidiscipline study recommendation. Actual property and rate derived from the newly drilled wells displayed a very reasonable match to the expected property from the model.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77299672","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}
S. Harris, Samita Santoshini, Sheleem Kashem, Thomas Viard, A. Levannier, Azeddine Benabbou
Conceptual limitations of existing gridding technologies often lead to undesirable simplifications to the modeling of structurally complex areas, and consequently poor predictions. We present a structural modeling and gridding workflow that limits these modeling compromises. A volume-based 3D structural model based on fault and horizon surfaces is constructed from input data that has undergone basic quality checking using a variety of techniques. The critical step in the grid creation is the definition of a flattened (‘depositional’) space that deforms the structural model mesh under mechanical constraints. A 3D ‘unstructured’ grid is created in the depositional space, based on ‘cutting’ a property-populated, regular cuboidal grid by the geological discontinuities. The tectonic consistency and better preservation of geodetic distance make the flattened space ideal for a range of property modeling approaches. The forward-deformation of the grid into true geological space tends to preserve the layer-orthogonality of the grid columns and makes the grid more suited to numerical simulation approximations. The final grid is unstructured, high quality and an accurate representation of the input structural model. The 3D structural model, depositional space transform and grid geometries all provide valuable information on the structural quality of the input data. The stretching and deforming of the orthogonal local axes in the transformation from depositional space to geological space are used to focus further effort on structural model quality assurance (QA). The key step in generating accurate property population and simulation models is the application of QA metrics on the grid geometry; the transformation from depositional space to geological space is used to generate a set of grid properties that highlight potential structural inconsistencies or data quality issues back in the structural model. We present several examples based on a range of structurally complex models, and demonstrate the downstream impact of applying this QA workflow throughout the stages of input data validation, structural model creation and grid creation.
{"title":"Complex Geological Modeling and Quality Assurance Using Unstructured Grids","authors":"S. Harris, Samita Santoshini, Sheleem Kashem, Thomas Viard, A. Levannier, Azeddine Benabbou","doi":"10.2118/193202-MS","DOIUrl":"https://doi.org/10.2118/193202-MS","url":null,"abstract":"\u0000 Conceptual limitations of existing gridding technologies often lead to undesirable simplifications to the modeling of structurally complex areas, and consequently poor predictions. We present a structural modeling and gridding workflow that limits these modeling compromises.\u0000 A volume-based 3D structural model based on fault and horizon surfaces is constructed from input data that has undergone basic quality checking using a variety of techniques. The critical step in the grid creation is the definition of a flattened (‘depositional’) space that deforms the structural model mesh under mechanical constraints. A 3D ‘unstructured’ grid is created in the depositional space, based on ‘cutting’ a property-populated, regular cuboidal grid by the geological discontinuities. The tectonic consistency and better preservation of geodetic distance make the flattened space ideal for a range of property modeling approaches. The forward-deformation of the grid into true geological space tends to preserve the layer-orthogonality of the grid columns and makes the grid more suited to numerical simulation approximations. The final grid is unstructured, high quality and an accurate representation of the input structural model.\u0000 The 3D structural model, depositional space transform and grid geometries all provide valuable information on the structural quality of the input data. The stretching and deforming of the orthogonal local axes in the transformation from depositional space to geological space are used to focus further effort on structural model quality assurance (QA). The key step in generating accurate property population and simulation models is the application of QA metrics on the grid geometry; the transformation from depositional space to geological space is used to generate a set of grid properties that highlight potential structural inconsistencies or data quality issues back in the structural model. We present several examples based on a range of structurally complex models, and demonstrate the downstream impact of applying this QA workflow throughout the stages of input data validation, structural model creation and grid creation.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"214 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74760605","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}
H. Asaadian, B. S. Soulgani, S. R. Gomari, Bahador Soltani Soulgani
Gas and liquid outlets length Study and its effect on Gas/liquid Cylindrical Cyclone (GLCC) separator performance. Gas body column length Study and its effect on GLCC separator performance. Inlet diameter Study and its effect on GLCC separator performance. Study of body column diameter and its effect on GLCC separator performance. Study of gas and liquid outlets diameter and its effect on GLCC separator performance. An experimental GLCC separator was designed and built in laboratory to determine its domain. The best operational domain is where the equilibrium liquid level placed below the inlet and between 1 L/D and 3 L/D of separator column. If it pass the inlet it causes liquid carry over and if it settles below the 3 L/D it creates gas carry under in the separator. Thus the equilibrium liquid level was measured for different range of liquid and gas flowrates. In this work the gas superficial velocity was set between 0.3 and 6 meter per second and for each gas superficial velocity, liquid superficial velocity was from 0.3 to 3.3 meter per second. Moreover, different parts of test separator was changed and their effects on the separator operating domain was studied. These changes are 12.7 mm reduction in inlet diameter size, 5 mm reduction in liquid outlet diameter size, 5 mm reduction in gas outlet diameter size, 0.12 meter reduction in gas column length, 25.4 mm reduction in column diameter size and 1.4 meter increment in outlet length. Based on this work the following results were obtained:Reducing the inlet diameter improves the GLCC separator performance. It allows more gas and liquid flowrates enter the separator for total separation by enhancing the centrifugal effect on liquid and gas phases.Reducing the liquid outlet diameter has negative effect in GLCC flowrates domain but this reduction can be used to control the equilibrium liquid level by a gate valve in liquid outlet leg.Reducing the gas outlet diameter has negative effect on GLCC performance. But in some situations controlling the amount of accumulated gas in GLCC can avoid liquid carry over in the system.Reduction in gas column length shows no effect on the separator flowrates domain.Increasing in length of outlet legs increases the friction force and limited the separator performance.Reduction in separator body diameter raises the chance of liquid carry over and gas carry under and has negative effect on flowrates domain. These findings from GLCC performance give the main guideline to design more efficient separator design for oil and gas fields. Proper designing makes separator performance domain wider whereas it creates separators more compact which in turn minimizes the cost of construction accordingly.
{"title":"Experimental Investigation over Effect of Geometrical Changes on Gas/Liquid Cylindrical Cyclone GLCC Separator","authors":"H. Asaadian, B. S. Soulgani, S. R. Gomari, Bahador Soltani Soulgani","doi":"10.2118/193029-MS","DOIUrl":"https://doi.org/10.2118/193029-MS","url":null,"abstract":"\u0000 Gas and liquid outlets length Study and its effect on Gas/liquid Cylindrical Cyclone (GLCC) separator performance. Gas body column length Study and its effect on GLCC separator performance. Inlet diameter Study and its effect on GLCC separator performance. Study of body column diameter and its effect on GLCC separator performance. Study of gas and liquid outlets diameter and its effect on GLCC separator performance.\u0000 An experimental GLCC separator was designed and built in laboratory to determine its domain. The best operational domain is where the equilibrium liquid level placed below the inlet and between 1 L/D and 3 L/D of separator column. If it pass the inlet it causes liquid carry over and if it settles below the 3 L/D it creates gas carry under in the separator. Thus the equilibrium liquid level was measured for different range of liquid and gas flowrates. In this work the gas superficial velocity was set between 0.3 and 6 meter per second and for each gas superficial velocity, liquid superficial velocity was from 0.3 to 3.3 meter per second. Moreover, different parts of test separator was changed and their effects on the separator operating domain was studied. These changes are 12.7 mm reduction in inlet diameter size, 5 mm reduction in liquid outlet diameter size, 5 mm reduction in gas outlet diameter size, 0.12 meter reduction in gas column length, 25.4 mm reduction in column diameter size and 1.4 meter increment in outlet length.\u0000 Based on this work the following results were obtained:Reducing the inlet diameter improves the GLCC separator performance. It allows more gas and liquid flowrates enter the separator for total separation by enhancing the centrifugal effect on liquid and gas phases.Reducing the liquid outlet diameter has negative effect in GLCC flowrates domain but this reduction can be used to control the equilibrium liquid level by a gate valve in liquid outlet leg.Reducing the gas outlet diameter has negative effect on GLCC performance. But in some situations controlling the amount of accumulated gas in GLCC can avoid liquid carry over in the system.Reduction in gas column length shows no effect on the separator flowrates domain.Increasing in length of outlet legs increases the friction force and limited the separator performance.Reduction in separator body diameter raises the chance of liquid carry over and gas carry under and has negative effect on flowrates domain.\u0000 These findings from GLCC performance give the main guideline to design more efficient separator design for oil and gas fields. Proper designing makes separator performance domain wider whereas it creates separators more compact which in turn minimizes the cost of construction accordingly.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"99 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82118239","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}
Thermal EOR projects are technically and economically challenging projects. Improving the geological understanding and implementing these geological concepts into the static model were key to increase the robustness of, not only the geological model but also of the dynamic simulation. The initial believe was that fine grained and mm scale laminated sediments act as vertical baffles for the steam distribution. The fine grained sands were low in permeability and the lamination were further reducing the vertical permeability. Grain size had the main impact on permeability and grain size was correlated with V-shale. Then, V-shale was used as a proxy for grain size and was integrated into a V-shale base porosity-permeability transformation. After modeling the baffles explicitly, it was shown that against the initial belief, the main control on fluid flow was not a patchy baffle distribution. Instead the reservoir was overall reduced in vertical permeability. A lager impact had the V-shale base poro-perm transform, predicting an order of magnitude permeability range for a given porosity. Reducing the impact of the facies also reduced overall the uncertainty and improved the predictive power of the models. This in turn, helped to take development decisions with much higher confidence.
{"title":"Integrated Geological Modeling for Higher Confidence Development Decisions, Sultanate of Oman","authors":"Bellmann Lars Hendrik","doi":"10.2118/193043-ms","DOIUrl":"https://doi.org/10.2118/193043-ms","url":null,"abstract":"\u0000 Thermal EOR projects are technically and economically challenging projects. Improving the geological understanding and implementing these geological concepts into the static model were key to increase the robustness of, not only the geological model but also of the dynamic simulation.\u0000 The initial believe was that fine grained and mm scale laminated sediments act as vertical baffles for the steam distribution. The fine grained sands were low in permeability and the lamination were further reducing the vertical permeability. Grain size had the main impact on permeability and grain size was correlated with V-shale. Then, V-shale was used as a proxy for grain size and was integrated into a V-shale base porosity-permeability transformation.\u0000 After modeling the baffles explicitly, it was shown that against the initial belief, the main control on fluid flow was not a patchy baffle distribution. Instead the reservoir was overall reduced in vertical permeability. A lager impact had the V-shale base poro-perm transform, predicting an order of magnitude permeability range for a given porosity. Reducing the impact of the facies also reduced overall the uncertainty and improved the predictive power of the models. This in turn, helped to take development decisions with much higher confidence.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"58 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80511789","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}
This presentation describes the efforts undertaken by ADNOC Gas Processing's Buhasa site to save electrical energy in the NGL extraction plant by minimizing fuel gas consumption in power generators. This also contributes to a reduction in flue gas emissions. During 2017, ADNOC Gas Processing pursued actions to save electrical energy in air fin coolers by implementing a sequential ON/OFF control logic to achieve a saving of 1,265,600 kWH. The implementation did not occur any costs, as the project was realized completely with in-house resources.
本报告介绍了ADNOC天然气加工公司Buhasa工厂通过最大限度地减少发电机的燃气消耗来节省NGL提取厂的电能所做的努力。这也有助于减少烟气排放。2017年，ADNOC Gas Processing通过实施顺序ON/OFF控制逻辑，采取措施节省空气翅片冷却器的电能，从而节省了1,265,600千瓦时。该项目的实施没有产生任何成本，因为该项目完全由内部资源实现。
{"title":"Electrical Energy Savings in NGL Extraction Plant by Implementing ON/OFF Sequence Logic Control for Fin Fan Coolers","authors":"Rashed Bametraf","doi":"10.2118/192931-MS","DOIUrl":"https://doi.org/10.2118/192931-MS","url":null,"abstract":"\u0000 This presentation describes the efforts undertaken by ADNOC Gas Processing's Buhasa site to save electrical energy in the NGL extraction plant by minimizing fuel gas consumption in power generators. This also contributes to a reduction in flue gas emissions.\u0000 During 2017, ADNOC Gas Processing pursued actions to save electrical energy in air fin coolers by implementing a sequential ON/OFF control logic to achieve a saving of 1,265,600 kWH. The implementation did not occur any costs, as the project was realized completely with in-house resources.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88677617","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}
Amitava Choudhuri, M. S. Jainal, Mustafa B. Adenan, J. Takei, Toslan Ali, M. Janor
An innovative work process for integrated and collaborative way of working has been developed and is being operationalized throughout all PETRONAS Carigali operating blocks, within Malaysia and also, in all International Countries wherein PETRONAS Carigali is the operating partner. This process is inline to the Company's vision for a phenomenal shift in the way that the company's workforce accomplishes its tasks, employing latest digital technologies and efficient work processes. Through this work process, the intention is to integrate all systems and tools, adopt collaboration between various work disciplines and come up with a novel work process that is lean with the prime objective of maximizing production and improving the production efficiency. This integrated and collaborative work process is being named as Reservoir Well Facility Management (RWFM), encompassing all the six production lenses and is thus an end-to-end business process. The geographical areas of operation of the Company are vast and scattered across the world. Thus, a need has been felt to standardize the work practices across all operating blocks in order to ensure that there is a standardized and integrated way of working at every work location. Also, there have been a number of digital solutions deployed over the last couple of years and the immediate need is to integrate all these solutions as well as to enhance their utilization. This RWFM work process will facilitate increased utilization of the tools as well as integrate all the current solutions. The new work process has been deployed as a program at most of the Assets of the Company. The process will take some time to be fully practiced and the program team will be looking at a stabilization period before the Assets actively implement it in their daily routine. There is a Change Management effort ongoing in parallel to assist the operationalization team and to bring in the mind set change to inculcate the new way of working. This paper will entail a detailed discussion on the work process and the operationalization activity undertaken by the focused team.
{"title":"Operationalization of a New Systematic Work Process at PETRONAS Carigali Sdn Bhd","authors":"Amitava Choudhuri, M. S. Jainal, Mustafa B. Adenan, J. Takei, Toslan Ali, M. Janor","doi":"10.2118/192814-MS","DOIUrl":"https://doi.org/10.2118/192814-MS","url":null,"abstract":"\u0000 An innovative work process for integrated and collaborative way of working has been developed and is being operationalized throughout all PETRONAS Carigali operating blocks, within Malaysia and also, in all International Countries wherein PETRONAS Carigali is the operating partner. This process is inline to the Company's vision for a phenomenal shift in the way that the company's workforce accomplishes its tasks, employing latest digital technologies and efficient work processes. Through this work process, the intention is to integrate all systems and tools, adopt collaboration between various work disciplines and come up with a novel work process that is lean with the prime objective of maximizing production and improving the production efficiency.\u0000 This integrated and collaborative work process is being named as Reservoir Well Facility Management (RWFM), encompassing all the six production lenses and is thus an end-to-end business process. The geographical areas of operation of the Company are vast and scattered across the world. Thus, a need has been felt to standardize the work practices across all operating blocks in order to ensure that there is a standardized and integrated way of working at every work location. Also, there have been a number of digital solutions deployed over the last couple of years and the immediate need is to integrate all these solutions as well as to enhance their utilization. This RWFM work process will facilitate increased utilization of the tools as well as integrate all the current solutions.\u0000 The new work process has been deployed as a program at most of the Assets of the Company. The process will take some time to be fully practiced and the program team will be looking at a stabilization period before the Assets actively implement it in their daily routine. There is a Change Management effort ongoing in parallel to assist the operationalization team and to bring in the mind set change to inculcate the new way of working. This paper will entail a detailed discussion on the work process and the operationalization activity undertaken by the focused team.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"201 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"80183082","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}
Jian Sun, Qi Li, Mingqiang Chen, L. Ren, Fengrui Sun, YongXiang Ai, K. Tang
The identification of oil and water layers (OWL) from well log data is an important task in petroleum exploration and engineering. At present, the commonly used methods for OWL identification are time-consuming, low accuracy or need better experience of researchers. Therefore, some machine learning methods have been developed to identify the lithology and OWL. Based on logging while drilling data, this paper optimizes machine learning methods to identify OWL while drilling. Recently, several computational algorithms have been used for OWL identification to improve the prediction accuracy. In this paper, we evaluate three popular machine learning methods, namely the one-against-rest support vector machine, one-against-one support vector machine, and random forest. First, we choose apposite training set data as a sample for model training. Then, GridSearch method was used to find the approximate range of reasonable parameters' value. And then using k-fold cross validation to optimize the final parameters and to avoid overfitting. Finally, choosing apposite test set data to verify the model. The method of using machine learning method to identify OWL while drilling has been successfully applied in Weibei oilfield. We select 1934 groups of well logging response data for 31 production wells. Among them, 198 groups of LWD data were selected as the test set data. Natural gamma, shale content, acoustic time difference, and deep-sensing logs were selected as input feature parameters. After GridSearch and 10-fold cross validation, the results suggest that random forest method is the best algorithm for supervised classification of OWL using well log data. The accuracy of the three classifiers after the calculation of the training set is greater than 90%, but their differences are relative large. For the test set, the calculated accuracy of the three classifiers is about 90%, with a small difference. The one-against-rest support vector machine classifier spends much more time than other methods. The one-against-one support vector machine classifier is the classifier which training set accuracy and test set accuracy are the lowest in three methods. Although all the calculation results have diffierences in accuracy of OWL identification, their accuracy is relatively high. For different reservoirs, taking into account the time cost and model calculation accuracy, we can use random forest and one-against-one support vector machine models to identify OWL in real time during drilling.
{"title":"Optimization of Models for Rapid Identification of Oil and Water Layers During Drilling - A Win-Win Strategy Based on Machine Learning","authors":"Jian Sun, Qi Li, Mingqiang Chen, L. Ren, Fengrui Sun, YongXiang Ai, K. Tang","doi":"10.2118/192833-MS","DOIUrl":"https://doi.org/10.2118/192833-MS","url":null,"abstract":"\u0000 The identification of oil and water layers (OWL) from well log data is an important task in petroleum exploration and engineering. At present, the commonly used methods for OWL identification are time-consuming, low accuracy or need better experience of researchers. Therefore, some machine learning methods have been developed to identify the lithology and OWL. Based on logging while drilling data, this paper optimizes machine learning methods to identify OWL while drilling.\u0000 Recently, several computational algorithms have been used for OWL identification to improve the prediction accuracy. In this paper, we evaluate three popular machine learning methods, namely the one-against-rest support vector machine, one-against-one support vector machine, and random forest. First, we choose apposite training set data as a sample for model training. Then, GridSearch method was used to find the approximate range of reasonable parameters' value. And then using k-fold cross validation to optimize the final parameters and to avoid overfitting. Finally, choosing apposite test set data to verify the model.\u0000 The method of using machine learning method to identify OWL while drilling has been successfully applied in Weibei oilfield. We select 1934 groups of well logging response data for 31 production wells. Among them, 198 groups of LWD data were selected as the test set data. Natural gamma, shale content, acoustic time difference, and deep-sensing logs were selected as input feature parameters. After GridSearch and 10-fold cross validation, the results suggest that random forest method is the best algorithm for supervised classification of OWL using well log data. The accuracy of the three classifiers after the calculation of the training set is greater than 90%, but their differences are relative large. For the test set, the calculated accuracy of the three classifiers is about 90%, with a small difference. The one-against-rest support vector machine classifier spends much more time than other methods. The one-against-one support vector machine classifier is the classifier which training set accuracy and test set accuracy are the lowest in three methods.\u0000 Although all the calculation results have diffierences in accuracy of OWL identification, their accuracy is relatively high. For different reservoirs, taking into account the time cost and model calculation accuracy, we can use random forest and one-against-one support vector machine models to identify OWL in real time during drilling.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87434967","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 wet gas flowmeter based on field-proven flowmeters and flow computers has been developed. The flowmeter is engineered by integrating the well-established SmartCone meter, a Pitot tube meter and filed mounted Flow Computer technologies in one wet gas metering solution. This combination exploits the characteristics of these two flow metering elements in wet gas flowrate measurement; The Cone measurement in wet gas is characterized by its relatively large gas measurement over-read with increasing liquid-loading, whereas this has a significantly lower impact on the gas flowrate measured by the Pitot tube. The DynaCone wet gas flowmeter has been in development over the past several years with particular emphasis being placed on developing a flexible flowmeter for broad operating conditions and applications including high turndown ratio, minimal pressure loss, measurement quality diagnostic, and performance characterization in industry-recognized wet gas flow loop. The wet gas performance has been demonstrated at CEESI wet gas flow loop yielding gas flowrates better than ±3% in Type I wet gas range, and better than ±5% in Type II without the input of liquid flowrate to correct for over-reading. Furthermore, uncertainties better than 2% and 3% for Type I & II respectively can be achieved if periodic liquid flowrate information is available for input.
{"title":"A Cost-Effective Dual-Element Metering System for Wet Gas Flowrate Measurement","authors":"Sami Halilah, K. Mokhtari","doi":"10.2118/192865-MS","DOIUrl":"https://doi.org/10.2118/192865-MS","url":null,"abstract":"\u0000 A wet gas flowmeter based on field-proven flowmeters and flow computers has been developed. The flowmeter is engineered by integrating the well-established SmartCone meter, a Pitot tube meter and filed mounted Flow Computer technologies in one wet gas metering solution. This combination exploits the characteristics of these two flow metering elements in wet gas flowrate measurement; The Cone measurement in wet gas is characterized by its relatively large gas measurement over-read with increasing liquid-loading, whereas this has a significantly lower impact on the gas flowrate measured by the Pitot tube.\u0000 The DynaCone wet gas flowmeter has been in development over the past several years with particular emphasis being placed on developing a flexible flowmeter for broad operating conditions and applications including high turndown ratio, minimal pressure loss, measurement quality diagnostic, and performance characterization in industry-recognized wet gas flow loop.\u0000 The wet gas performance has been demonstrated at CEESI wet gas flow loop yielding gas flowrates better than ±3% in Type I wet gas range, and better than ±5% in Type II without the input of liquid flowrate to correct for over-reading. Furthermore, uncertainties better than 2% and 3% for Type I & II respectively can be achieved if periodic liquid flowrate information is available for input.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"65 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86405853","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}
Cesar Montoya, Ahmed Aladawy, Ameen Malkawi, Rafael Adolfo Lastra Melo
Downhole gas compression is an artificial lift means that aims to increase production, maximize recovery and delay onset of liquid loading from gas wells. Being a technology not widely implemented yet, its application, benefits, operating window and limitations are not deeply managed by the oil & gas industry community. The compressor boosts gas flow rates by increasing the pressure drawdown in the well proportionally to inlet pressure reduction. The required pressure ratio needs to meet the discharge pressure requirements to overcome well head pressure, column weight and pressure losses across the tubing, but the larger pressure ratio is the higher outlet temperature will be, which may become a limiting factor due to completion, compressor and process specs. Fluid velocity also varies across different casing sections, carrying with changes in liquid volume fraction (LVF) and flow regimes. In general, compressors are known to be low efficient handling liquids, therefore a close investigation on the LVF and flow patterns at inlet conditions must be very well understood for downhole applications. Well modeling and sensitivity analysis will be used in this paper to illustrate in detail the well performance representation with downhole gas application along with a comparative analysis with surface gas compression to evaluate potential gains. Results and observations about these parameters, along with methodologies to calculate inlet/outlet conditions will also be described in this paper, adding to the existing literature a new holistic approach for analyzing gas well performance operated with downhole compressors.
{"title":"Gas Well Performance Analysis with Downhole Gas Compression","authors":"Cesar Montoya, Ahmed Aladawy, Ameen Malkawi, Rafael Adolfo Lastra Melo","doi":"10.2118/193310-MS","DOIUrl":"https://doi.org/10.2118/193310-MS","url":null,"abstract":"\u0000 Downhole gas compression is an artificial lift means that aims to increase production, maximize recovery and delay onset of liquid loading from gas wells. Being a technology not widely implemented yet, its application, benefits, operating window and limitations are not deeply managed by the oil & gas industry community.\u0000 The compressor boosts gas flow rates by increasing the pressure drawdown in the well proportionally to inlet pressure reduction. The required pressure ratio needs to meet the discharge pressure requirements to overcome well head pressure, column weight and pressure losses across the tubing, but the larger pressure ratio is the higher outlet temperature will be, which may become a limiting factor due to completion, compressor and process specs. Fluid velocity also varies across different casing sections, carrying with changes in liquid volume fraction (LVF) and flow regimes. In general, compressors are known to be low efficient handling liquids, therefore a close investigation on the LVF and flow patterns at inlet conditions must be very well understood for downhole applications.\u0000 Well modeling and sensitivity analysis will be used in this paper to illustrate in detail the well performance representation with downhole gas application along with a comparative analysis with surface gas compression to evaluate potential gains. Results and observations about these parameters, along with methodologies to calculate inlet/outlet conditions will also be described in this paper, adding to the existing literature a new holistic approach for analyzing gas well performance operated with downhole compressors.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"112 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86875260","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}
Muhammad Kabir Abba, A. Abbas, A. Al-Otaibi, G. Nasr
Enhanced gas recovery (EGR) by CO2 injection and sequestration is receiving increased attention within the research community. This is as a result of its potential to be an avenue for the simultaneous additional recovery of natural gas from the reservoir and provide a safe CO2 sequestration site. However, the major problem with this technology lies in the excessive mixing of the injected CO2 and the nascent natural gas (CH4) during the displacement process. This excessive mixing is the reason why the technology has not been widely patronised, given that the recovered CH4 will be heavily contaminated with the injected CO2 thereby making it "lacking" as sales gas after recovery. This hinders the market value of the recovered CH4 and eventually renders it not viable economically. Hence, highlighting the factors responsible for the mixing could provide technical solution to minimise the mixing phenomenon during EGR. This research focuses on the temperature effects and the orientation of the injection pattern of the technique. An experimental core flooding simulation was carried out at a temperature of 50°C and a pressure of 1300 psig and varying injection rates of 0.2 - 0.5 ml/min on Grey Berea sandstone core sample with the sample situated in both vertical and horizontal orientations. It was observed that at higher temperature (50°C) suitable for many gas reservoirs, the disperstion coefficient increased significantly compared to our earlier work (Abba, Abbas, & Nasr, 2017) at 40°C by a factor of 2.3. This trend was due to the increased energy of the gas molecules at the observed conditions, thereby increasing their mobilities. Conversely, the dispersion coefficient also increased significantly by a factor of 3.4 in the horizontal orientation at lower injection rates compared to the vertical core flooding with the concentration profiles showing significant capillary tailing effects at higher flowrates. This signified the effect of gravity in the horizontal orientation was more pronounced at lower injection rates during the injection of CO2 and this will have tremendous effect on the flow behavior of supercritical CO2 during the gas-gas displacement process.
{"title":"Enhanced Gas Recovery by CO2 Injection and Sequestration: Effects of Temperature, Vertical and Horizontal Orientations on Dispersion Coefficient","authors":"Muhammad Kabir Abba, A. Abbas, A. Al-Otaibi, G. Nasr","doi":"10.2118/192699-MS","DOIUrl":"https://doi.org/10.2118/192699-MS","url":null,"abstract":"\u0000 Enhanced gas recovery (EGR) by CO2 injection and sequestration is receiving increased attention within the research community. This is as a result of its potential to be an avenue for the simultaneous additional recovery of natural gas from the reservoir and provide a safe CO2 sequestration site. However, the major problem with this technology lies in the excessive mixing of the injected CO2 and the nascent natural gas (CH4) during the displacement process. This excessive mixing is the reason why the technology has not been widely patronised, given that the recovered CH4 will be heavily contaminated with the injected CO2 thereby making it \"lacking\" as sales gas after recovery. This hinders the market value of the recovered CH4 and eventually renders it not viable economically. Hence, highlighting the factors responsible for the mixing could provide technical solution to minimise the mixing phenomenon during EGR. This research focuses on the temperature effects and the orientation of the injection pattern of the technique. An experimental core flooding simulation was carried out at a temperature of 50°C and a pressure of 1300 psig and varying injection rates of 0.2 - 0.5 ml/min on Grey Berea sandstone core sample with the sample situated in both vertical and horizontal orientations. It was observed that at higher temperature (50°C) suitable for many gas reservoirs, the disperstion coefficient increased significantly compared to our earlier work (Abba, Abbas, & Nasr, 2017) at 40°C by a factor of 2.3. This trend was due to the increased energy of the gas molecules at the observed conditions, thereby increasing their mobilities. Conversely, the dispersion coefficient also increased significantly by a factor of 3.4 in the horizontal orientation at lower injection rates compared to the vertical core flooding with the concentration profiles showing significant capillary tailing effects at higher flowrates. This signified the effect of gravity in the horizontal orientation was more pronounced at lower injection rates during the injection of CO2 and this will have tremendous effect on the flow behavior of supercritical CO2 during the gas-gas displacement process.","PeriodicalId":11079,"journal":{"name":"Day 4 Thu, November 15, 2018","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76943700","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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