Scale presents a significant challenge in any context where flow is involved. In the oil and gas sector scale associated problems are notorious because of the significant volumes of brine that are involved at any stage of production. In addition, the formation brines are usually extremely concentrated when it comes to electrolytes that are prone to form scale. The real problematic scales are usually considered to be barite (BaSO4) and pyrite (FeS2, or mixed iron sulfides). The approach to remove them is usually to drive the solubility equilibrium towards solution by simply stabilizing the ions that are involved. That is usually done by coordination of the ions with a ligand that favors binding to the particular cation in question. For pyrite the challenge is then to identify a ligand that strongly coordinates Fe2+ whereas in the case of barite the focus will be on Ba2+. This is the classical approach to mostly target the cation and it has mostly been dealt with in the form of various chelating agents. We show results firstly, where newly designed cation binders provide a 20 % higher dissolving power than the second best and where binding pockets are designed for anions. This new binding mode will enable the design of a structure that simultaneously binds cations and anions and this is where we are heading with the current results. The efficiency of chelating agents is significantly dependent on pH this topic will be touched upon in a computational study here the calculated structure and the associated calculated binding energy will be discussed and related to dissolving power. The result show that ab initio calculations are nice supplements to experimental endeavors.
{"title":"Taking a New Approach Towards Chelating Agents for Scale Removal","authors":"T. Sølling, M. Mahmoud, M. Pittelkow","doi":"10.2523/iptc-22604-ea","DOIUrl":"https://doi.org/10.2523/iptc-22604-ea","url":null,"abstract":"\u0000 Scale presents a significant challenge in any context where flow is involved. In the oil and gas sector scale associated problems are notorious because of the significant volumes of brine that are involved at any stage of production. In addition, the formation brines are usually extremely concentrated when it comes to electrolytes that are prone to form scale. The real problematic scales are usually considered to be barite (BaSO4) and pyrite (FeS2, or mixed iron sulfides). The approach to remove them is usually to drive the solubility equilibrium towards solution by simply stabilizing the ions that are involved. That is usually done by coordination of the ions with a ligand that favors binding to the particular cation in question. For pyrite the challenge is then to identify a ligand that strongly coordinates Fe2+ whereas in the case of barite the focus will be on Ba2+. This is the classical approach to mostly target the cation and it has mostly been dealt with in the form of various chelating agents. We show results firstly, where newly designed cation binders provide a 20 % higher dissolving power than the second best and where binding pockets are designed for anions. This new binding mode will enable the design of a structure that simultaneously binds cations and anions and this is where we are heading with the current results. The efficiency of chelating agents is significantly dependent on pH this topic will be touched upon in a computational study here the calculated structure and the associated calculated binding energy will be discussed and related to dissolving power. The result show that ab initio calculations are nice supplements to experimental endeavors.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75470410","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
The non-Newtonian behavior of oil/water emulsion in the ESP stage is still not well understood. The industry relies on existing empirical correlations, which only valid for production pipelines without considering the effect of shear force acting on the system. This paper will present the analytical modeling of emulsion rheology in the ESP stage and its effect on ESP boosting pressure. An extensive experimental data set validates the analytical model accuracy. The Brinkman empirical correlation is the baseline of the analytical model development. Emulsion rheology in the ESP stage depends on many factors. Dimensionless analysis by the Buckingham-Phi theorem indicates that at least three parameters play an essential role in the emulsion rheology at the pump stage. Those parameters are concatenated and applied as the modified function of Brinkman empirical correlation. In addition, the pump boosting pressure performance observed experimentally to study the emulsion rheology effect at the ESP. More than a thousand experiment data points employed to test the proposed model, and its comparison is studied statistically. The dimensional analysis prevails that the turbulence effect at the stage condition reflected by the Reynolds number, the droplet size effect represented by the Weber number and the Strouhal numbers relates to the shearing effect due to impeller rotation. The analytical model and experiment perform with two different oil viscosity, 45 cp and 70 cp. The results reveal that the higher oil viscosity reaches the inversion point at a lower water fraction since the turbulence decreases with higher oil viscosity. The emulsion rheology from the experiment result shows a significant increase of emulsion viscosity at water fraction close to the inversion point since the increase of hydrodynamic forces due to a higher number of water droplets. The emulsion rheology model aligns with the experiment results for the inversion point at around 35% and 32% water-fraction, respectively. The emulsion rheology model shows a good agreement with the experimental data with a 15% standard deviation of relative error. Increasing water fraction up to the inversion point deteriorates pump boosting pressure since the high friction loss occurs due to higher emulsion viscosity. Nevertheless, as the water fraction passes theinversion point, the boosting pressure starts to rebound as the water turns into the continuous phase. The formation of oil/water emulsion in the ESP is inevitable during production operation and consequently affects the pump boosting pressure. The inversion point phenomena occur at a different range of water fractions for different oil viscosity. A better understanding of emulsion rheology at the pump stage will lead to an accurate artificial lift design and eventually avoid operation failure during production well operation.
{"title":"Analytical and Experimental Study of Oil/water Emulsion in Multi Stage Electric Submersible Pump","authors":"M. R. Ridlah, Haiwen Zhu, Hong-quan Zhang","doi":"10.2523/iptc-22407-ms","DOIUrl":"https://doi.org/10.2523/iptc-22407-ms","url":null,"abstract":"\u0000 The non-Newtonian behavior of oil/water emulsion in the ESP stage is still not well understood. The industry relies on existing empirical correlations, which only valid for production pipelines without considering the effect of shear force acting on the system. This paper will present the analytical modeling of emulsion rheology in the ESP stage and its effect on ESP boosting pressure. An extensive experimental data set validates the analytical model accuracy.\u0000 The Brinkman empirical correlation is the baseline of the analytical model development. Emulsion rheology in the ESP stage depends on many factors. Dimensionless analysis by the Buckingham-Phi theorem indicates that at least three parameters play an essential role in the emulsion rheology at the pump stage. Those parameters are concatenated and applied as the modified function of Brinkman empirical correlation. In addition, the pump boosting pressure performance observed experimentally to study the emulsion rheology effect at the ESP. More than a thousand experiment data points employed to test the proposed model, and its comparison is studied statistically.\u0000 The dimensional analysis prevails that the turbulence effect at the stage condition reflected by the Reynolds number, the droplet size effect represented by the Weber number and the Strouhal numbers relates to the shearing effect due to impeller rotation. The analytical model and experiment perform with two different oil viscosity, 45 cp and 70 cp. The results reveal that the higher oil viscosity reaches the inversion point at a lower water fraction since the turbulence decreases with higher oil viscosity. The emulsion rheology from the experiment result shows a significant increase of emulsion viscosity at water fraction close to the inversion point since the increase of hydrodynamic forces due to a higher number of water droplets. The emulsion rheology model aligns with the experiment results for the inversion point at around 35% and 32% water-fraction, respectively. The emulsion rheology model shows a good agreement with the experimental data with a 15% standard deviation of relative error. Increasing water fraction up to the inversion point deteriorates pump boosting pressure since the high friction loss occurs due to higher emulsion viscosity. Nevertheless, as the water fraction passes theinversion point, the boosting pressure starts to rebound as the water turns into the continuous phase. The formation of oil/water emulsion in the ESP is inevitable during production operation and consequently affects the pump boosting pressure. The inversion point phenomena occur at a different range of water fractions for different oil viscosity. A better understanding of emulsion rheology at the pump stage will lead to an accurate artificial lift design and eventually avoid operation failure during production well operation.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75862043","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}
Khursaniyah Gas Plant (KGP) had successfully invested in retrofitting one of its air-cooled heat exchanger systems with a variable frequency drive (VFD). This air-cooled heat exchanger system is an integral part in the cogeneration plant operation, and one where its reliability directly affects the cogeneration plant's availability. The original system arrangement consists of a two-double-deck heat exchanger, and three forced draft fin fans operating simultaneously at full speed. A failure or trip to one of these fin fans will automatically trigger a logic known as "Runback," plant power generation and steam production are reduced by 50% and 30% respectively when logic is activated, this protection logic is configured in order to protect the gas turbine hot gas path parts and maintain their temperature within the allowable safe working limits. The new retrofitted VFD allows controlling of the fin fans electric motors rotational speed via controlling both voltage and frequency input to the motors. The primary objective which drove Khursaniyah gas plant to implement this project was to improve the cogeneration plant utilization. This objective was achieved by maintaining the heat exchanger output temperature at an operating range between 420F and 440F, via variable speed fin fans regardless to any changes in the ambient temperature. Several modifications to the existing system components were implemented in order to achieve this objective, some of these modifications include: increasing the fan's blade width, increasing of driver motor's rated torque, and installation of a closed feedback loop control system. The new enhanced system is now capable of operating the cogeneration plant with two fin fans at 100% cogeneration plant operating capacity, while one fin fan can be offline for any planned, or unplanned maintenance activities. An expensive alternative to this retrofitting project was to add additional fin fan to the heat exchanger system. However, adding a new fin fan requires replacement of the double-deck heat exchanger to another unit with larger capacity and additional footprint to accommodate the new extra fan. This retrofitting project required none of the above and was deemed and proven to be the most efficient and practical option to resolve this chronic issue.
{"title":"Retrofitting Air-Cooled Heat Exchangers with Variable Frequency Drive: Challenges and Benefits","authors":"Nezar Ba-Aqeel","doi":"10.2523/iptc-22669-ea","DOIUrl":"https://doi.org/10.2523/iptc-22669-ea","url":null,"abstract":"\u0000 Khursaniyah Gas Plant (KGP) had successfully invested in retrofitting one of its air-cooled heat exchanger systems with a variable frequency drive (VFD). This air-cooled heat exchanger system is an integral part in the cogeneration plant operation, and one where its reliability directly affects the cogeneration plant's availability. The original system arrangement consists of a two-double-deck heat exchanger, and three forced draft fin fans operating simultaneously at full speed. A failure or trip to one of these fin fans will automatically trigger a logic known as \"Runback,\" plant power generation and steam production are reduced by 50% and 30% respectively when logic is activated, this protection logic is configured in order to protect the gas turbine hot gas path parts and maintain their temperature within the allowable safe working limits.\u0000 The new retrofitted VFD allows controlling of the fin fans electric motors rotational speed via controlling both voltage and frequency input to the motors. The primary objective which drove Khursaniyah gas plant to implement this project was to improve the cogeneration plant utilization. This objective was achieved by maintaining the heat exchanger output temperature at an operating range between 420F and 440F, via variable speed fin fans regardless to any changes in the ambient temperature. Several modifications to the existing system components were implemented in order to achieve this objective, some of these modifications include: increasing the fan's blade width, increasing of driver motor's rated torque, and installation of a closed feedback loop control system.\u0000 The new enhanced system is now capable of operating the cogeneration plant with two fin fans at 100% cogeneration plant operating capacity, while one fin fan can be offline for any planned, or unplanned maintenance activities. An expensive alternative to this retrofitting project was to add additional fin fan to the heat exchanger system. However, adding a new fin fan requires replacement of the double-deck heat exchanger to another unit with larger capacity and additional footprint to accommodate the new extra fan. This retrofitting project required none of the above and was deemed and proven to be the most efficient and practical option to resolve this chronic issue.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76072674","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}
Abeer Al-Abdullatif, A. Khan, Ayoub Ibrahim Awaji, Abdulhakim Alhussain, Ahmed Garwan
Halliburton uses the term "local content" to describe programs to develop and use local resources in providing our services in that host country. Local content requirements vary by country, but commonly include providing employment opportunities to local citizens, procurement of goods and services from within the country, manufacturing and value addition through partnerships with and development of local entities, training programs to develop the technical skills of local individuals and businesses, and carry out research and development for finding indigenous alternates of imported materials. In almost all cases, local content requirements are mandated by the laws of the countries where we operate. Adhering to and improving local content is an important part of Halliburton's commitment to support the countries in which it operates and it also brings benefits for both Halliburton and local communities. In this paper, we share a case study of how Halliburton carried out the process of localizing chemical manufacturing in Saudi Arabia, the steps taken, and support extended in developing the local suppliers. Meeting local content requirements requires precise collaboration and communication between regional and country management teams, compliance with host country laws and regulations, adherence to Halliburton company policies, and meeting the quality standards the National Operating Company which is the end user in most cases. The methodology for achieving effective localization results started with setting the right strategy and putting challenging but achievable targets. This localization initiative exemplifies company efforts to create value in every aspect of the company's business through the In-Kingdom Total Value Add (iktva) program mandated by the national operating company in the country. Having a local source of manufacturing and supply chain mitigates any disruptions like the one we saw during COVID 19 whereby the movement across borders was partially closed and supply chain globally was disrupted. Any local souring effectively diminishes the impact of any such disruptions. This initiative considered more than 50 Halliburton commercial chemical products and resulted in more than 10 successful replacements. Halliburton was able to export three products to company's operations outside Saudi Arabia. Partnering with Saudi Aramco, chamber of commerce and local manufacturers and suppliers in this program will drive additional domestic value creation to support a rapidly changing economic environment and foster future prosperity.
{"title":"Local Manufacturing of Oilfield Chemicals- Mitigating Potential Future Disruptions While Supporting Local Content Program","authors":"Abeer Al-Abdullatif, A. Khan, Ayoub Ibrahim Awaji, Abdulhakim Alhussain, Ahmed Garwan","doi":"10.2523/iptc-22094-ms","DOIUrl":"https://doi.org/10.2523/iptc-22094-ms","url":null,"abstract":"\u0000 Halliburton uses the term \"local content\" to describe programs to develop and use local resources in providing our services in that host country. Local content requirements vary by country, but commonly include providing employment opportunities to local citizens, procurement of goods and services from within the country, manufacturing and value addition through partnerships with and development of local entities, training programs to develop the technical skills of local individuals and businesses, and carry out research and development for finding indigenous alternates of imported materials. In almost all cases, local content requirements are mandated by the laws of the countries where we operate.\u0000 Adhering to and improving local content is an important part of Halliburton's commitment to support the countries in which it operates and it also brings benefits for both Halliburton and local communities. In this paper, we share a case study of how Halliburton carried out the process of localizing chemical manufacturing in Saudi Arabia, the steps taken, and support extended in developing the local suppliers. Meeting local content requirements requires precise collaboration and communication between regional and country management teams, compliance with host country laws and regulations, adherence to Halliburton company policies, and meeting the quality standards the National Operating Company which is the end user in most cases. The methodology for achieving effective localization results started with setting the right strategy and putting challenging but achievable targets.\u0000 This localization initiative exemplifies company efforts to create value in every aspect of the company's business through the In-Kingdom Total Value Add (iktva) program mandated by the national operating company in the country.\u0000 Having a local source of manufacturing and supply chain mitigates any disruptions like the one we saw during COVID 19 whereby the movement across borders was partially closed and supply chain globally was disrupted. Any local souring effectively diminishes the impact of any such disruptions.\u0000 This initiative considered more than 50 Halliburton commercial chemical products and resulted in more than 10 successful replacements. Halliburton was able to export three products to company's operations outside Saudi Arabia. Partnering with Saudi Aramco, chamber of commerce and local manufacturers and suppliers in this program will drive additional domestic value creation to support a rapidly changing economic environment and foster future prosperity.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86474077","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}
There are many reservoir simulation applications for multiphase flow in porous media where hysteresis or path-dependence of both relative permeability and capillary pressure functions are crucial to capture. The formation of a residual non-wetting phase saturation due to capillary trapping in a hysteretic manner carries significant implications to some major petroleum development processes such as EOR or water-alternating-gas (WAG), as well as environmental processes, such as geologic CO2 storage. In this paper, we focus on accurately quantifying how much of the injected CO2 gets trapped underground due to relative permeability hysteresis only and the most efficient way to model this physical phenomenon. Over the years, multiple methods for implementing hysteresis into reservoir simulators were introduced to capture the trapping phenomenon. However, these complex methods created numerical difficulties especially when flow reversal happens, creating nonlinear solver convergence issues due to discontinuous derivatives. A new technique has been introduced recently with a claim of smoother behavior and better non-linear solver performance. The main goal of this study is to assess this new technique by looking at both nonlinear solver performance as well as the method accuracy compared to previous standard models. Here, three models are implemented in an implicit state-of-the-art simulator especially developed for this study. This is equipped with nonlinear-convergence-enhancing techniques such as Appleyard saturation chopping and different upstream weighting. The hysteresis models are implemented for relative permeability of the non-wetting phase only and has been ignored in the wetting phase, and the study also neglects the capillary pressure hysteresis. The paper presents the theoretical background of the models and their implementations as well as the significance of accounting for hysteresis in such applications. Then, simulation results and numerical analyses are presented for a 1D gravity segregation case in a hypothetical CO2 storage setting. The results show that the new model proved to offer a better numerical handle of the hysteresis in reservoir simulation. This improvement is particularly significant in normal moderate CFL number scenarios, while in the very low or very high scenarios, the improvement is modest. All models can produce similar results if their relative permeability curves have been fitted well. It is important to keep in mind that even though the numerical differences are not huge in this simple test case, these results show indication of where difficulties can arise from when this simple test case is taken into more complicated settings. Capturing the accurate physics for such processes, namely underground CO2 storage, is vital as studies show that this accounts for a great deal of the CO2 trapped underground; however, this may be a difficult task for most commercial simulators. In this work, we analyze different mod
{"title":"Numerical Analysis for Relative Permeability Hysteresis Models in Reservoir Simulation of CO2 Trapping in Underground Carbon Storage","authors":"A. Al Ali","doi":"10.2523/iptc-22239-ms","DOIUrl":"https://doi.org/10.2523/iptc-22239-ms","url":null,"abstract":"\u0000 There are many reservoir simulation applications for multiphase flow in porous media where hysteresis or path-dependence of both relative permeability and capillary pressure functions are crucial to capture. The formation of a residual non-wetting phase saturation due to capillary trapping in a hysteretic manner carries significant implications to some major petroleum development processes such as EOR or water-alternating-gas (WAG), as well as environmental processes, such as geologic CO2 storage. In this paper, we focus on accurately quantifying how much of the injected CO2 gets trapped underground due to relative permeability hysteresis only and the most efficient way to model this physical phenomenon.\u0000 Over the years, multiple methods for implementing hysteresis into reservoir simulators were introduced to capture the trapping phenomenon. However, these complex methods created numerical difficulties especially when flow reversal happens, creating nonlinear solver convergence issues due to discontinuous derivatives. A new technique has been introduced recently with a claim of smoother behavior and better non-linear solver performance. The main goal of this study is to assess this new technique by looking at both nonlinear solver performance as well as the method accuracy compared to previous standard models. Here, three models are implemented in an implicit state-of-the-art simulator especially developed for this study. This is equipped with nonlinear-convergence-enhancing techniques such as Appleyard saturation chopping and different upstream weighting.\u0000 The hysteresis models are implemented for relative permeability of the non-wetting phase only and has been ignored in the wetting phase, and the study also neglects the capillary pressure hysteresis. The paper presents the theoretical background of the models and their implementations as well as the significance of accounting for hysteresis in such applications. Then, simulation results and numerical analyses are presented for a 1D gravity segregation case in a hypothetical CO2 storage setting. The results show that the new model proved to offer a better numerical handle of the hysteresis in reservoir simulation. This improvement is particularly significant in normal moderate CFL number scenarios, while in the very low or very high scenarios, the improvement is modest. All models can produce similar results if their relative permeability curves have been fitted well. It is important to keep in mind that even though the numerical differences are not huge in this simple test case, these results show indication of where difficulties can arise from when this simple test case is taken into more complicated settings.\u0000 Capturing the accurate physics for such processes, namely underground CO2 storage, is vital as studies show that this accounts for a great deal of the CO2 trapped underground; however, this may be a difficult task for most commercial simulators. In this work, we analyze different mod","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88100758","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}
Shuang Ai, Youzhi Duan, Yashu Chen, Chen Gao, R. Rached
Shape memory sand control screen completion based on shape memory polymer not only has the advantages of simple process and easy to run in hole, like independent screen, but also can achieve the sand management effect of gravel filling. Therefore, shape memory sand control screen has wide application prospects. However, since the shape memory material is temperature-sensitive, a large number of laboratory experiments are needed to evaluate its expansion, seepage and sand retaining capabilities, as well as optimize the polymer system and screen structure. A performance evaluation experiment system for full-size shape memory screen prototype was developed. The device can describe the parameters of the shape memory screen during the expansion process and after expansion in real time and quantitatively, such as permeability, outer diameter and residual stress. The expansion behavior of screen prototype is controlled by step heating the passing through fluid to simulate the screen run in hole operation. 60 sets of experiments were carried out using the device. The expansion performance, seepage performance and sand control performance of shape memory screens were evaluated. Shape memory polymer formulation and screen structure are also optimized. The research shows that the optimized shape memory sand control screen densely filled annulus and effectively supports the wellbore after expansion. The permeability of the expanded screen can be up to 35µm2, the displacement pressure difference can be less than 1kPa, and the sand control precision can be up to 0.061mm. Therefore, shape memory sand control screen can be used for sand control completion of oil and gas wells with limited well site conditions such as long horizontal wells, complex wells and offshore wells. This paper presents an experiment device to evaluate the performance of shape memory screen, the dynamic expansion behavior is described during the expansion process and after expansion in real time and quantitatively.
{"title":"Experimental Study of Shape Memory Sand Control Screen","authors":"Shuang Ai, Youzhi Duan, Yashu Chen, Chen Gao, R. Rached","doi":"10.2523/iptc-22357-ms","DOIUrl":"https://doi.org/10.2523/iptc-22357-ms","url":null,"abstract":"\u0000 Shape memory sand control screen completion based on shape memory polymer not only has the advantages of simple process and easy to run in hole, like independent screen, but also can achieve the sand management effect of gravel filling. Therefore, shape memory sand control screen has wide application prospects. However, since the shape memory material is temperature-sensitive, a large number of laboratory experiments are needed to evaluate its expansion, seepage and sand retaining capabilities, as well as optimize the polymer system and screen structure.\u0000 A performance evaluation experiment system for full-size shape memory screen prototype was developed. The device can describe the parameters of the shape memory screen during the expansion process and after expansion in real time and quantitatively, such as permeability, outer diameter and residual stress. The expansion behavior of screen prototype is controlled by step heating the passing through fluid to simulate the screen run in hole operation. 60 sets of experiments were carried out using the device. The expansion performance, seepage performance and sand control performance of shape memory screens were evaluated. Shape memory polymer formulation and screen structure are also optimized.\u0000 The research shows that the optimized shape memory sand control screen densely filled annulus and effectively supports the wellbore after expansion. The permeability of the expanded screen can be up to 35µm2, the displacement pressure difference can be less than 1kPa, and the sand control precision can be up to 0.061mm. Therefore, shape memory sand control screen can be used for sand control completion of oil and gas wells with limited well site conditions such as long horizontal wells, complex wells and offshore wells.\u0000 This paper presents an experiment device to evaluate the performance of shape memory screen, the dynamic expansion behavior is described during the expansion process and after expansion in real time and quantitatively.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89580194","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}
Yen Pinng Chan, Muhammad Yazuwan Sallij Muhammad Yasin, I. Muhamad
Amidst global push towards sustainable energy, efforts to drive down greenhouse gas (GHG) emissions towards net zero across all upstream assets and new developments are expected to intensify. This task has proven to be far more challenging for existing, aging offshore facilities both technically and commercially. This paper will share various fit-for-purpose options identified through rigorous front-end loading (FEL) processes which can be implemented on existing, aging facilities to accelerate and realize sustainable GHG emission reduction efforts across all business value chain. Essence of decarbonization is in the reduction of carbon dioxide (CO2) and hydrocarbon emissions. Apart from carbon tax inclusion in decision making, proactive directives in zero continuous hydrocarbon venting and flaring in upstream facilities while maximizing renewable energy applications has already set the momentum. Beyond that, lies the task of developing sustainable carbon abatement strategies for existing, aging facilities. Up to eight (8) concepts were explored through feasibility study at FEL assessing the extent of brownfield modification, emissions reduction, and associated costs. Concepts range from cost-efficient vent to flare conversions to CAPEX-intensive gas injection and sequestration solutions. Options with monetization potential such as floating compressed natural gas (FCNG), liquid or condensate recovery system (CRS) and gas liquefaction are within consideration as well. Value improvement beyond facilities design life is influenced by the sustainability of solutions introduced. There are 25 tons of CO2e in every part of methane (CH4) released in vent gas, which is a common design for offshore facilities aged more than 30 years. Efforts in emissions reduction is therefore deemed most suitably carried out in both a short- and long-term manner, which is replicable regardless of a facility's age. Short term, fit-for-purpose solution of converting existing vent stacks into flare stacks with cyclone separator-caisson system is projected to be able to significantly reduce GHG emissions up to 70% in the span of 3 years. Leading towards net zero, mid and long-term efforts through gas injection and sequestration including monetization strategies will be more sustainable as they demonstrate potential of up to 95% GHG emissions reduction within field life. Particularly for monetization opportunities such as pipeline export, CNG, CRS and gas liquefaction, area development strategy is recommended to establish economy of scale. Ability to synergize carbon abatement with capital projects innovatively to achieve positive economic returns while transitioning into a global environment of sustainability is crucial. Decarbonization efforts especially for existing, aging upstream facilities requires firstly, a strong managerial aspiration in the sustainability agenda; Secondly, expertise of operations to balance life cycle costs against carbon abatement investments
{"title":"Towards Realizing Net Zero Carbon Emissions for Sustainability of Existing and Aging Offshore Facilities","authors":"Yen Pinng Chan, Muhammad Yazuwan Sallij Muhammad Yasin, I. Muhamad","doi":"10.2523/iptc-22559-ms","DOIUrl":"https://doi.org/10.2523/iptc-22559-ms","url":null,"abstract":"\u0000 Amidst global push towards sustainable energy, efforts to drive down greenhouse gas (GHG) emissions towards net zero across all upstream assets and new developments are expected to intensify. This task has proven to be far more challenging for existing, aging offshore facilities both technically and commercially. This paper will share various fit-for-purpose options identified through rigorous front-end loading (FEL) processes which can be implemented on existing, aging facilities to accelerate and realize sustainable GHG emission reduction efforts across all business value chain.\u0000 Essence of decarbonization is in the reduction of carbon dioxide (CO2) and hydrocarbon emissions. Apart from carbon tax inclusion in decision making, proactive directives in zero continuous hydrocarbon venting and flaring in upstream facilities while maximizing renewable energy applications has already set the momentum. Beyond that, lies the task of developing sustainable carbon abatement strategies for existing, aging facilities.\u0000 Up to eight (8) concepts were explored through feasibility study at FEL assessing the extent of brownfield modification, emissions reduction, and associated costs. Concepts range from cost-efficient vent to flare conversions to CAPEX-intensive gas injection and sequestration solutions. Options with monetization potential such as floating compressed natural gas (FCNG), liquid or condensate recovery system (CRS) and gas liquefaction are within consideration as well.\u0000 Value improvement beyond facilities design life is influenced by the sustainability of solutions introduced. There are 25 tons of CO2e in every part of methane (CH4) released in vent gas, which is a common design for offshore facilities aged more than 30 years. Efforts in emissions reduction is therefore deemed most suitably carried out in both a short- and long-term manner, which is replicable regardless of a facility's age. Short term, fit-for-purpose solution of converting existing vent stacks into flare stacks with cyclone separator-caisson system is projected to be able to significantly reduce GHG emissions up to 70% in the span of 3 years.\u0000 Leading towards net zero, mid and long-term efforts through gas injection and sequestration including monetization strategies will be more sustainable as they demonstrate potential of up to 95% GHG emissions reduction within field life. Particularly for monetization opportunities such as pipeline export, CNG, CRS and gas liquefaction, area development strategy is recommended to establish economy of scale. Ability to synergize carbon abatement with capital projects innovatively to achieve positive economic returns while transitioning into a global environment of sustainability is crucial.\u0000 Decarbonization efforts especially for existing, aging upstream facilities requires firstly, a strong managerial aspiration in the sustainability agenda; Secondly, expertise of operations to balance life cycle costs against carbon abatement investments","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89110650","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}
Shallow reflectors which generate surface related multiples, can deteriorate image quality and hamper amplitude analysis. Typically, in land seismic data, the severe noise level and near-surface complexity make surface multiples difficult to identify and remove. In this paper, we present a least-squares multiple imaging (LSMI) driven de-multiple method which targets short and medium period surface multiples. The process involves inversion for a shallow multiple generating reflectivity, which is then used to drive the multiple modeling. The method allows true amplitude modeling, so minimal adaption is required at the subtraction stage. We demonstrate this method on a high-density land dataset acquired in Algeria. The results show that the multiple generator image gives better near-surface illumination and continuity compared to the conventional primary imaging approach. The strong multiple energy present in the near angle is largely suppressed, leading to less ringing and a more interpretable seismic image. Compared with surface-consistent deconvolution, the proposed de-multiple approach extends the amount of reverberation being attenuated, this is particularly effective on low-frequency multiples.
{"title":"Least-Squares Multiple Imaging for 3D Surface-Related Multiple Elimination on Land Data","authors":"Brandon Li, M. Miorali, K. Mills, G. Poole","doi":"10.2523/iptc-21935-ea","DOIUrl":"https://doi.org/10.2523/iptc-21935-ea","url":null,"abstract":"\u0000 Shallow reflectors which generate surface related multiples, can deteriorate image quality and hamper amplitude analysis. Typically, in land seismic data, the severe noise level and near-surface complexity make surface multiples difficult to identify and remove. In this paper, we present a least-squares multiple imaging (LSMI) driven de-multiple method which targets short and medium period surface multiples. The process involves inversion for a shallow multiple generating reflectivity, which is then used to drive the multiple modeling. The method allows true amplitude modeling, so minimal adaption is required at the subtraction stage. We demonstrate this method on a high-density land dataset acquired in Algeria. The results show that the multiple generator image gives better near-surface illumination and continuity compared to the conventional primary imaging approach. The strong multiple energy present in the near angle is largely suppressed, leading to less ringing and a more interpretable seismic image. Compared with surface-consistent deconvolution, the proposed de-multiple approach extends the amount of reverberation being attenuated, this is particularly effective on low-frequency multiples.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78729207","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}
One of the primary tasks of a production engineer at an oil field is to maximize oil production from a field comprising multiple wells, while respecting a multitude of constraints related to operational limitations of components, component reliability, interaction between wells, environmental concerns, and operational costs. This is a multi-objective multi-constraint problem involving multiple physics models that interact with each other. Further, the total number of optimization parameters and constraints grows linearly with the size of the field. This makes the problem computationally intensive for oil fields with hundreds of wells and thus the direct use of a standard optimization algorithm will be inefficient. This paper describes a computationally tractable and scalable approach to solve this problem.
{"title":"Production Optimization of a Large Network of Oil Wells with Electrical Submersible Pumps as the Artificial Lift System","authors":"Anisha Roy, Senthilkumar Datchanamoorthy, Nagappa Sharad, Sangeeta Nundy","doi":"10.2523/iptc-22155-ms","DOIUrl":"https://doi.org/10.2523/iptc-22155-ms","url":null,"abstract":"\u0000 One of the primary tasks of a production engineer at an oil field is to maximize oil production from a field comprising multiple wells, while respecting a multitude of constraints related to operational limitations of components, component reliability, interaction between wells, environmental concerns, and operational costs. This is a multi-objective multi-constraint problem involving multiple physics models that interact with each other. Further, the total number of optimization parameters and constraints grows linearly with the size of the field. This makes the problem computationally intensive for oil fields with hundreds of wells and thus the direct use of a standard optimization algorithm will be inefficient. This paper describes a computationally tractable and scalable approach to solve this problem.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84815057","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}
Well Integrity Monitoring provides means to protect the people, environment, reputation and assets of oil and gas operations globally. While being a vital tool for preventing safety and economic mishaps in oil and gas wells, it is also one of the primary responsibilities of the Production Engineer. Three examples of technological advancements in the area of real-time data monitoring and intelligent-field visualization systems, which have largely enhanced the capabilities of the Production Engineer to monitor Well Integrity parameters across large fields are presented. The real-time data monitoring and intelligent-field visualization system functions based on a feedback loop system, which continuously monitors well integrity parameters such as pressure, temperature, voltage and current. The output from the probes installed in the well are passed to a Central Processing Unit where the electrical signal is processed, converted to well integrity parameters and compared with set points. Deviation are recorded and anomalies are flagged off for prompt intervention. Continuous real-time monitoring of Annuli Pressure, Well Head Pressure and Voltage/Current led to timely identification of Well Head Casing Leak, Failed Well Head Valve and corroded casing respectively in the three cases studied. The most significant new finding is that anomalies in other cases typically take up to one year to identify due to less frequent integrity survey practice adopted in fields where the intelligent-field technology is non-existent. This is important because timely intervention made possible by real-time monitoring systems safeguards corporation assets, reputation and the environment. The implemented Intelligent Field Remote Surveillance and Monitoring System has shown its significance in optimizing well integrity solutions in large fields, protecting people, enabling prompt intervention and saving the environment. To achieve this target, collaboration within several departments and organizations is required within an oil company. As such, the concept can only be successful if it is part of the corporate vision and is driven at a high level in any company.
{"title":"Well Integrity Solutions Using Intelligent Field Remote Surveillance and Monitoring Systems","authors":"Haider Al-Hajji, Abiola S. Onikoyi","doi":"10.2523/iptc-22302-ea","DOIUrl":"https://doi.org/10.2523/iptc-22302-ea","url":null,"abstract":"\u0000 Well Integrity Monitoring provides means to protect the people, environment, reputation and assets of oil and gas operations globally. While being a vital tool for preventing safety and economic mishaps in oil and gas wells, it is also one of the primary responsibilities of the Production Engineer. Three examples of technological advancements in the area of real-time data monitoring and intelligent-field visualization systems, which have largely enhanced the capabilities of the Production Engineer to monitor Well Integrity parameters across large fields are presented.\u0000 The real-time data monitoring and intelligent-field visualization system functions based on a feedback loop system, which continuously monitors well integrity parameters such as pressure, temperature, voltage and current. The output from the probes installed in the well are passed to a Central Processing Unit where the electrical signal is processed, converted to well integrity parameters and compared with set points. Deviation are recorded and anomalies are flagged off for prompt intervention.\u0000 Continuous real-time monitoring of Annuli Pressure, Well Head Pressure and Voltage/Current led to timely identification of Well Head Casing Leak, Failed Well Head Valve and corroded casing respectively in the three cases studied. The most significant new finding is that anomalies in other cases typically take up to one year to identify due to less frequent integrity survey practice adopted in fields where the intelligent-field technology is non-existent. This is important because timely intervention made possible by real-time monitoring systems safeguards corporation assets, reputation and the environment.\u0000 The implemented Intelligent Field Remote Surveillance and Monitoring System has shown its significance in optimizing well integrity solutions in large fields, protecting people, enabling prompt intervention and saving the environment.\u0000 To achieve this target, collaboration within several departments and organizations is required within an oil company. As such, the concept can only be successful if it is part of the corporate vision and is driven at a high level in any company.","PeriodicalId":10974,"journal":{"name":"Day 2 Tue, February 22, 2022","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2022-02-21","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75934670","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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