Natsuda Toasudjai, Chanya Lordkratok, Kelly Fecho, Poppoom Tipdontree
In the Gulf of Thailand (GOT), deep directional drilling wells are planned with two runs using motor and adjustable-gage-stabilizer (AGS) bottom hole assembly (BHA) in the 6-1/8-in. hole section or the rotary-steerable-system (RSS) BHA. However, the cost of the RSS is not economical for some wells. The paper discusses the challenges of drilling in the high temperature environment and explains the engineering and analysis that resulted in a one run hole section with a motor BHA. The extreme temperature elastomer (XT) motor was paired with an agitator system to facilitate the transfer of BHA weight for effective weight-on-bit (WOB) while sliding in long tangent or curve for great depths and temperature more than 150 degree Celsius (⁰C) well. Exhaustive BHA analysis, namely hydraulics, drill-string torque-drag and various sensitivity studies were performed for optimal placement of the agitator and shock sub in the BHA for the best friction reduction and least damaging vibration effect on BHA components. The simulation capabilities were enhanced by trail runs, analyzing historical performance and empirical data to implement step change improvements in the next BHA. The XT motor with agitator-system BHA enabled smooth sliding and fast rate of penetration (ROP) across the entirely true vertical depth (TVD) range of the 6-1/8-in. hole. There was no BHA hanging up when sliding in deep sections of the well, demonstrating stable tool-face control while sliding, which translated to an overall efficient penetration rate. The 6-1/8-in. hole sections drilled with the XT motor and agitator-system BHA demonstrated 30 percent (%) faster ROP than similar TVD sections drilled with a motor without an agitator-system BHA. For example, a 6-1/8-in. hole with 1360-meter (m) drilled in long tangent at 41degree (°) inclination was successfully drilled in one run from shoe to 2584m MD of the well TD in 27 hours, with an average on bottom ROP of 51 meter per hour(m/hr).
{"title":"Improvement Drilling Efficiency by Using Mud Motor and Agitator Bha in 6 1/8-in. Hole: Gulf of Thailand","authors":"Natsuda Toasudjai, Chanya Lordkratok, Kelly Fecho, Poppoom Tipdontree","doi":"10.4043/31359-ms","DOIUrl":"https://doi.org/10.4043/31359-ms","url":null,"abstract":"\u0000 In the Gulf of Thailand (GOT), deep directional drilling wells are planned with two runs using motor and adjustable-gage-stabilizer (AGS) bottom hole assembly (BHA) in the 6-1/8-in. hole section or the rotary-steerable-system (RSS) BHA. However, the cost of the RSS is not economical for some wells. The paper discusses the challenges of drilling in the high temperature environment and explains the engineering and analysis that resulted in a one run hole section with a motor BHA.\u0000 The extreme temperature elastomer (XT) motor was paired with an agitator system to facilitate the transfer of BHA weight for effective weight-on-bit (WOB) while sliding in long tangent or curve for great depths and temperature more than 150 degree Celsius (⁰C) well. Exhaustive BHA analysis, namely hydraulics, drill-string torque-drag and various sensitivity studies were performed for optimal placement of the agitator and shock sub in the BHA for the best friction reduction and least damaging vibration effect on BHA components. The simulation capabilities were enhanced by trail runs, analyzing historical performance and empirical data to implement step change improvements in the next BHA.\u0000 The XT motor with agitator-system BHA enabled smooth sliding and fast rate of penetration (ROP) across the entirely true vertical depth (TVD) range of the 6-1/8-in. hole. There was no BHA hanging up when sliding in deep sections of the well, demonstrating stable tool-face control while sliding, which translated to an overall efficient penetration rate. The 6-1/8-in. hole sections drilled with the XT motor and agitator-system BHA demonstrated 30 percent (%) faster ROP than similar TVD sections drilled with a motor without an agitator-system BHA. For example, a 6-1/8-in. hole with 1360-meter (m) drilled in long tangent at 41degree (°) inclination was successfully drilled in one run from shoe to 2584m MD of the well TD in 27 hours, with an average on bottom ROP of 51 meter per hour(m/hr).","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"139-140 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79157979","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}
Currently, there has been a surge in evaluating the effectiveness of various hybrid enhanced oil recovery (EOR) methods as they combine the benefits of standalone processes. This study focuses on laboratory investigation to evaluate synergy between polymer and nanoparticles (NP), as their combination can simultaneously alter capillary and viscous forces. N-vinyl-pyrrolidone-based partially hydrolyzed polyacrylamide and silica oxide nanoparticles are used in this study. The standalone polymer, nanofluid (NF), and combined polymer-nanofluid solutions are prepared in different salinities (1200-40,000 ppm). The zeta potential of solutions is measured to determine the stability of NF at various salinities. Contact angle measurements are performed to determine the optimum concentration of NP. A series of rheological experiments are accomplished at different nanoparticle concentrations (0.05, 0.1, 0.15 wt%), temperatures (25-80 °C), and polymer concentrations (500 to 3000 ppm). Additionally, a long-term stability test was conducted over thirty days at 80°C on nano-assisted-polymer fluid over a long period. Zeta potential results proved that the stability of nanofluids decreases with an increase in solution salinity. However, the addition of polymer has a positive impact on the stability of NF and is stable up to 40 000 ppm salinity. The nanoparticles have shown potential in altering the wettability of the rock toward the intermediate wet conditions. A maximum deviation of 55° in contact angle is observed for a 0.1 wt% NP solution and is selected as optimum concentration. Rheology studies illustrate that the addition of NP increases the viscosity of the polymer solution by 25%. All nano-assisted-polymer solutions tested in this study showed shear thinning behavior. Long-term thermal stability of nano-assisted-polymer solution indicates that the solution achieves equilibrium after 5 days and maintains target viscosity of 4 cP. The addition of polymer has positively impacted the salinity tolerance of nanoparticles. Additionally, nanoparticles improved the viscosity of the polymer solution. This study will open new doors for the hybrid EOR method.
{"title":"Laboratory Investigation of Hybrid Nano-Assisted-Polymer Method for EOR Applications in Carbonate Reservoirs","authors":"M. Zhangaliyev, M. Hashmet, P. Pourafshary","doi":"10.4043/31398-ms","DOIUrl":"https://doi.org/10.4043/31398-ms","url":null,"abstract":"\u0000 Currently, there has been a surge in evaluating the effectiveness of various hybrid enhanced oil recovery (EOR) methods as they combine the benefits of standalone processes. This study focuses on laboratory investigation to evaluate synergy between polymer and nanoparticles (NP), as their combination can simultaneously alter capillary and viscous forces.\u0000 N-vinyl-pyrrolidone-based partially hydrolyzed polyacrylamide and silica oxide nanoparticles are used in this study. The standalone polymer, nanofluid (NF), and combined polymer-nanofluid solutions are prepared in different salinities (1200-40,000 ppm). The zeta potential of solutions is measured to determine the stability of NF at various salinities. Contact angle measurements are performed to determine the optimum concentration of NP. A series of rheological experiments are accomplished at different nanoparticle concentrations (0.05, 0.1, 0.15 wt%), temperatures (25-80 °C), and polymer concentrations (500 to 3000 ppm). Additionally, a long-term stability test was conducted over thirty days at 80°C on nano-assisted-polymer fluid over a long period.\u0000 Zeta potential results proved that the stability of nanofluids decreases with an increase in solution salinity. However, the addition of polymer has a positive impact on the stability of NF and is stable up to 40 000 ppm salinity. The nanoparticles have shown potential in altering the wettability of the rock toward the intermediate wet conditions. A maximum deviation of 55° in contact angle is observed for a 0.1 wt% NP solution and is selected as optimum concentration. Rheology studies illustrate that the addition of NP increases the viscosity of the polymer solution by 25%. All nano-assisted-polymer solutions tested in this study showed shear thinning behavior. Long-term thermal stability of nano-assisted-polymer solution indicates that the solution achieves equilibrium after 5 days and maintains target viscosity of 4 cP.\u0000 The addition of polymer has positively impacted the salinity tolerance of nanoparticles. Additionally, nanoparticles improved the viscosity of the polymer solution. This study will open new doors for the hybrid EOR method.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"5 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85314217","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 paper discussed the development of an Ultra-Low Interfacial Tension (IFT) foaming surfactant based on a combination of improved as-synthesized surfactant (CBH) consist of as-synthesized oleic amido propyl betaine with mixtures of co-solvents and PETRONAS’ in-house patented foaming-based surfactant (IVF) which consist of amphoteric and anionic surfactant; as well as the performance evaluation of the surfactant in Enhanced Oil Revery (EOR) application. CBH and PETRONAS (IVF) foam-based surfactants were used in the formulation as ultra-low IFT and foaming components, respectively. The surfactant's development has been highlighted, and the findings have been discussed in detail. Due to the good foaming and IFT output at ultra-low levels, the combination of 0.3wt.% IVF and CBH at a ratio of 2: 8 was suggested. The addition of a non-ionic scleroglucan polymer from the polysaccharide group was chosen to study the stabilizing effect to the foam and the ultra-low IFT value of the formulation. Based on the findings, the presence of scleroglucan in the formulation has a significant effect on the performance of IFT and foam of the formulation when compared to the original formulation.
{"title":"New Formulation of Ultra-Low Ift Surfactant for Potential Eor Application","authors":"Norhidayah Ahmad Wazir, Shazleen Saadon, A. Ramli","doi":"10.4043/31449-ms","DOIUrl":"https://doi.org/10.4043/31449-ms","url":null,"abstract":"\u0000 The paper discussed the development of an Ultra-Low Interfacial Tension (IFT) foaming surfactant based on a combination of improved as-synthesized surfactant (CBH) consist of as-synthesized oleic amido propyl betaine with mixtures of co-solvents and PETRONAS’ in-house patented foaming-based surfactant (IVF) which consist of amphoteric and anionic surfactant; as well as the performance evaluation of the surfactant in Enhanced Oil Revery (EOR) application. CBH and PETRONAS (IVF) foam-based surfactants were used in the formulation as ultra-low IFT and foaming components, respectively. The surfactant's development has been highlighted, and the findings have been discussed in detail. Due to the good foaming and IFT output at ultra-low levels, the combination of 0.3wt.% IVF and CBH at a ratio of 2: 8 was suggested. The addition of a non-ionic scleroglucan polymer from the polysaccharide group was chosen to study the stabilizing effect to the foam and the ultra-low IFT value of the formulation. Based on the findings, the presence of scleroglucan in the formulation has a significant effect on the performance of IFT and foam of the formulation when compared to the original formulation.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"40 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87541752","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 project under consideration witnesses IR (Insulation Resistance) degradation on reconnecting the subsea system to the FPSO (Floating Production Storage and Offloading) after a prolonged period of disconnection. The IR of the system eventually regains its expected value after some time interval. The present research investigates the causes of IR degradation and the possible mechanisms behind IR recovery after system startup. The prime focus of this work is on the umbilical utilized in the field.
{"title":"Investigation of Intermittent Loss of Electrical Integrity in Subsea Control System","authors":"Mohit Bharatbhai Tanna, Wayne Rayner","doi":"10.4043/31626-ms","DOIUrl":"https://doi.org/10.4043/31626-ms","url":null,"abstract":"\u0000 \u0000 \u0000 The project under consideration witnesses IR (Insulation Resistance) degradation on reconnecting the subsea system to the FPSO (Floating Production Storage and Offloading) after a prolonged period of disconnection. The IR of the system eventually regains its expected value after some time interval. The present research investigates the causes of IR degradation and the possible mechanisms behind IR recovery after system startup. The prime focus of this work is on the umbilical utilized in the field.\u0000","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"42 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83663546","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}
Mohammed H. Ali, Caterina Galli, Jose Felipe Freire Machado, Giordano Martinelli
There has never been a more challenging time for the energy industry. In the subsea sector, the search for optimised costs, minimized carbon emissions, and maximized performance is set to intensify as oil prices continue their unpredictable trajectory. At the same time, the risks to equipment, to people, to the local terrain and seascape will remain. What the industry needs in the face of all this is cost certainty and reduced CO2 output, derived not just from technical certainty but also execution certainty. With these concerns front of mind, it is no surprise that research into the performance of subsea equipment and service suppliers published by [1] Kimberlite LLC in May 2020 showed some concern about the capability of suppliers" offerings to meet those future requirements. 45% of those surveyed said that more advances were needed in subsea trees, citing reliability, cost, lead times, and size as areas for improvement. In addition, subsea manifolds were separately cited by another 12%, as a technology area that could be advanced. As part of the goal to achieve carbon net zero status, every single aspect of subsea operations is an opportunity to drive improvement. Through the work undertaken as described in this paper to drive standardization across the industry around the world, it can be shown that even equipment like manifolds – that come with some entrenched design and operational philosophies behind them – can deliver substantial improvements to the areas that matter most such as reduction of carbon footprint.
{"title":"Standardization and Carbon Footprint Reduction of Subsea Manifolds – Is Ready and Now!","authors":"Mohammed H. Ali, Caterina Galli, Jose Felipe Freire Machado, Giordano Martinelli","doi":"10.4043/31435-ms","DOIUrl":"https://doi.org/10.4043/31435-ms","url":null,"abstract":"\u0000 There has never been a more challenging time for the energy industry. In the subsea sector, the search for optimised costs, minimized carbon emissions, and maximized performance is set to intensify as oil prices continue their unpredictable trajectory.\u0000 At the same time, the risks to equipment, to people, to the local terrain and seascape will remain. What the industry needs in the face of all this is cost certainty and reduced CO2 output, derived not just from technical certainty but also execution certainty.\u0000 With these concerns front of mind, it is no surprise that research into the performance of subsea equipment and service suppliers published by [1] Kimberlite LLC in May 2020 showed some concern about the capability of suppliers\" offerings to meet those future requirements.\u0000 45% of those surveyed said that more advances were needed in subsea trees, citing reliability, cost, lead times, and size as areas for improvement. In addition, subsea manifolds were separately cited by another 12%, as a technology area that could be advanced.\u0000 As part of the goal to achieve carbon net zero status, every single aspect of subsea operations is an opportunity to drive improvement. Through the work undertaken as described in this paper to drive standardization across the industry around the world, it can be shown that even equipment like manifolds – that come with some entrenched design and operational philosophies behind them – can deliver substantial improvements to the areas that matter most such as reduction of carbon footprint.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"77 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76561599","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}
Sebastien Kamgang, Andal Pierre, Rakesh Neupane, J. P. García, Segun A. Jebutu, Chukwuka Enyioha, J. Mccaslin, Caitlin Papso, Christine Hahn
The Gulf of Mexico (GOM) is home to thousands of deep water wells in a variety of status such as production, temporary or permanently abandoned. Regardless of the status of the well, the condition and integrity of the cement sheath behind casing is critical for the safety, performance, economics and life span of the well. For temporary or permanent abandonment, the condition of the cement sheath is an integral part of the overall risk assessment and associated well controlled measures designed to contain and prevent migration of undesired fluids to surface. Challenges related to the GOM environment highly influence the successful placement of the cement behind the casing and its subsequent evaluation. With typical water depths in excess of 2,500ft., a wellbore trajectory can reach and exceed 30,000ft measured depth and can be highly inclined. Hydrocarbons bearing formations may be unconsolidated sands with high risk of sand production. Within the same wellbore, a succession of pressure-depleted zones, water zones, hydrocarbons zones, high pressure zones, faults, etc. may be encountered. The typical completion strategy is referred to as cased-hole frac-packing. This completion methodology provides substantial benefits in alleviating potential sand production, reservoir fluids production stabilization, and reduction of near wellbore skin by creating network of high-conductivity channels deeply into the formation. However, the creation of these deep fractured-channels poses additional risks for out-of-zone fracture growth along the wellbore in the absence of a competent cement sheath. Different types of cements and placement techniques are used in the GOM. These cements are specifically designed to address each challenge expected in any wellbore–highly depleted zones (thief zones), over-pressured zones, unconsolidated high porosity/permeability zones, highly inclined wellbores, etc. In addition to the complexity of the different cement recipe, the conditions inside the wellbore are of equal importance during the cement evaluation–borehole size, borehole fluid (oil vs. water), borehole fluid density, solids content, gasified fluids, etc. This paper focuses on two cement evaluation technologies. The first technology, based on an ultrasonic compressional wave, presents the distinctive advantage of reducing borehole fluids influences such as highly attenuating oil based or synthetic muds. The second technology uses innovative electro-magnetic acoustic transducers (EMAT). The EMAT acoustic signal is generated directly in the casing wall, making the measurement wellbore-fluid neutral. Multiple wave modes enables qualitative and quantitative interpretation in a wide range of slurry densities, including light-weight and foam cements. This technology provides the industry most direct solid behind-pipe evaluation through the attenuation of a shear wave which is a unique indication of solids. Selection of either technology, provides GOM operators with add
{"title":"Cement Evaluation Case Studies; Application of Multiphysics Measurements to Address Different Challenges in Deepwater Gulf of Mexico Environment","authors":"Sebastien Kamgang, Andal Pierre, Rakesh Neupane, J. P. García, Segun A. Jebutu, Chukwuka Enyioha, J. Mccaslin, Caitlin Papso, Christine Hahn","doi":"10.4043/31601-ms","DOIUrl":"https://doi.org/10.4043/31601-ms","url":null,"abstract":"\u0000 The Gulf of Mexico (GOM) is home to thousands of deep water wells in a variety of status such as production, temporary or permanently abandoned. Regardless of the status of the well, the condition and integrity of the cement sheath behind casing is critical for the safety, performance, economics and life span of the well. For temporary or permanent abandonment, the condition of the cement sheath is an integral part of the overall risk assessment and associated well controlled measures designed to contain and prevent migration of undesired fluids to surface.\u0000 Challenges related to the GOM environment highly influence the successful placement of the cement behind the casing and its subsequent evaluation. With typical water depths in excess of 2,500ft., a wellbore trajectory can reach and exceed 30,000ft measured depth and can be highly inclined. Hydrocarbons bearing formations may be unconsolidated sands with high risk of sand production. Within the same wellbore, a succession of pressure-depleted zones, water zones, hydrocarbons zones, high pressure zones, faults, etc. may be encountered. The typical completion strategy is referred to as cased-hole frac-packing. This completion methodology provides substantial benefits in alleviating potential sand production, reservoir fluids production stabilization, and reduction of near wellbore skin by creating network of high-conductivity channels deeply into the formation. However, the creation of these deep fractured-channels poses additional risks for out-of-zone fracture growth along the wellbore in the absence of a competent cement sheath.\u0000 Different types of cements and placement techniques are used in the GOM. These cements are specifically designed to address each challenge expected in any wellbore–highly depleted zones (thief zones), over-pressured zones, unconsolidated high porosity/permeability zones, highly inclined wellbores, etc. In addition to the complexity of the different cement recipe, the conditions inside the wellbore are of equal importance during the cement evaluation–borehole size, borehole fluid (oil vs. water), borehole fluid density, solids content, gasified fluids, etc.\u0000 This paper focuses on two cement evaluation technologies. The first technology, based on an ultrasonic compressional wave, presents the distinctive advantage of reducing borehole fluids influences such as highly attenuating oil based or synthetic muds. The second technology uses innovative electro-magnetic acoustic transducers (EMAT). The EMAT acoustic signal is generated directly in the casing wall, making the measurement wellbore-fluid neutral. Multiple wave modes enables qualitative and quantitative interpretation in a wide range of slurry densities, including light-weight and foam cements. This technology provides the industry most direct solid behind-pipe evaluation through the attenuation of a shear wave which is a unique indication of solids. Selection of either technology, provides GOM operators with add","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"7 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90820991","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 is a machine train consists of gas turbine driving an air-cooled synchronous generator (3600 rpm and 80 MW rated power), which showed increasing vibration levels on the generator bearings after each shutdown/startup event starting October 2020. A multichannel analyzer was hooked to collect the data during cold startup. Generator bearings showed high casing vibration levels close to alarm setpoints. The review of data during the transient modes (startup/shutdown) and at steady state indicated a clear symptom of couple-unbalance of the generator rotor without significant effect on the turbine bearings. Onsite balancing activity showed non-linear synchronous rotor response (different influence coefficient between the trial and correction runs), also a repeatability test (two similar runs without changing the balancing weights) on the generator rotor showed non repeatable synchronous response. Based on the above observations it was recommended to perform a borescope on the generator rotor. The investigation revealed that the root cause of the non-repeatable behavior was the sand ingress from the makeup generator air breather due to lack of proper maintenance. Dry cleaning of the rotor carried out and sand was removed by vacuum, then filters/gaskets replaced with new and healthy ones. Later, machine started with very acceptable vibration levels well below alarm setpoints. This case study will outline how to identify the nonlinear synchronous rotor response based on the balancing influence vector calculations using the transient polar plots data.
{"title":"Resolution of Non-Repeatable Synchronous Rotor Response of a Power Generator","authors":"Mohammed Ashour Mr., Mustafa Shalabi Mr.","doi":"10.4043/31670-ms","DOIUrl":"https://doi.org/10.4043/31670-ms","url":null,"abstract":"\u0000 This is a machine train consists of gas turbine driving an air-cooled synchronous generator (3600 rpm and 80 MW rated power), which showed increasing vibration levels on the generator bearings after each shutdown/startup event starting October 2020.\u0000 A multichannel analyzer was hooked to collect the data during cold startup. Generator bearings showed high casing vibration levels close to alarm setpoints. The review of data during the transient modes (startup/shutdown) and at steady state indicated a clear symptom of couple-unbalance of the generator rotor without significant effect on the turbine bearings.\u0000 Onsite balancing activity showed non-linear synchronous rotor response (different influence coefficient between the trial and correction runs), also a repeatability test (two similar runs without changing the balancing weights) on the generator rotor showed non repeatable synchronous response.\u0000 Based on the above observations it was recommended to perform a borescope on the generator rotor. The investigation revealed that the root cause of the non-repeatable behavior was the sand ingress from the makeup generator air breather due to lack of proper maintenance. Dry cleaning of the rotor carried out and sand was removed by vacuum, then filters/gaskets replaced with new and healthy ones. Later, machine started with very acceptable vibration levels well below alarm setpoints.\u0000 This case study will outline how to identify the nonlinear synchronous rotor response based on the balancing influence vector calculations using the transient polar plots data.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"106 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75740810","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}
Ying-xian Liu, Hongfu Shi, Zhongbo Xu, Wenjun Zhang, Xinpeng Wang
The Bohai bay is rich in oil and natural gas resources. Over the past 40 years, a series of different types of large and medium-sized offshore oil and gas fields have been successfully discovered and developed. The newly discovers, however, is marginal either smaller in size or poor in reservoir quality which can't be economically and efficiently developed with the current conventional exploitation methods. The development of such marginal assets is of great significant for the the sustainability of Bohai production. In this paper, L oilfield is taken as an example to explain how to establish a framework in developing such marginal oilfields cost-effectively through multi-disciplinary cooperation. The L oil field is one of the typical marginal green-oil fields discovered recently in the Bohai Bay which characterized as low OOIP, limited certain reservoir spaces for well placement and challenges economically for standalone development (Adeogun Oyebimpe, August 2018, Mohamed, A. Zakariya.March 2003). In addition, primarily thin oil layers at the average single layer thickness only 2.1 m, high crude oil viscosity at the average of 2000mpa·s, and low single well productivity less than 300 barrels per day. However, the L oil field geographically is next to a large oil field which is only 12km away. How to maximize the success chance of penetrating the sweet spot of those thin layers, and therefore achieve higher initial oil productivity, to form a complete injection-production well pattern for long period stability in production and to minimize capital investment through joint development with surrounding oilfields is the way out for L oilfield development.
渤海湾蕴藏着丰富的油气资源。40年来，我国成功发现和开发了一系列不同类型的大中型海上油气田。然而，新发现的油田规模较小或储层质量较差，不能采用现有的常规开发方法进行经济高效的开发。这些边际资产的开发对渤海地区的可持续生产具有重要意义。本文以L油田为例，阐述了如何通过多学科合作，建立经济高效的边际油田开发框架。L油田是最近在渤海湾发现的典型边际绿色油田之一，其特点是OOIP低，某些储层空间有限，并且独立开发面临经济挑战(Adeogun Oyebimpe, 2018年8月，Mohamed, A. Zakariya)。2003年3月)。此外，油层以薄层为主，平均单层厚度仅为2.1 m，原油粘度高，平均为2000mpa·s，单井产能较低，不足300桶/天。然而，L油田在地理上紧邻一个大油田，距离只有12公里。如何通过与周边油田联合开发，最大限度地提高薄层甜点的穿透成功率，从而获得较高的初始产油量，形成完整的注采井网，实现长期稳定生产，最大限度地减少资金投入，是L油田开发的出路。
{"title":"Cost Effective Framework of Integrated Development of Offshore Marginal Oilfields - Case Study of a Heavy Oil Reservoir with Thin Layers","authors":"Ying-xian Liu, Hongfu Shi, Zhongbo Xu, Wenjun Zhang, Xinpeng Wang","doi":"10.4043/31478-ms","DOIUrl":"https://doi.org/10.4043/31478-ms","url":null,"abstract":"\u0000 The Bohai bay is rich in oil and natural gas resources. Over the past 40 years, a series of different types of large and medium-sized offshore oil and gas fields have been successfully discovered and developed. The newly discovers, however, is marginal either smaller in size or poor in reservoir quality which can't be economically and efficiently developed with the current conventional exploitation methods. The development of such marginal assets is of great significant for the the sustainability of Bohai production.\u0000 In this paper, L oilfield is taken as an example to explain how to establish a framework in developing such marginal oilfields cost-effectively through multi-disciplinary cooperation. The L oil field is one of the typical marginal green-oil fields discovered recently in the Bohai Bay which characterized as low OOIP, limited certain reservoir spaces for well placement and challenges economically for standalone development (Adeogun Oyebimpe, August 2018, Mohamed, A. Zakariya.March 2003). In addition, primarily thin oil layers at the average single layer thickness only 2.1 m, high crude oil viscosity at the average of 2000mpa·s, and low single well productivity less than 300 barrels per day. However, the L oil field geographically is next to a large oil field which is only 12km away. How to maximize the success chance of penetrating the sweet spot of those thin layers, and therefore achieve higher initial oil productivity, to form a complete injection-production well pattern for long period stability in production and to minimize capital investment through joint development with surrounding oilfields is the way out for L oilfield development.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"16 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72976326","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}
Kuhanesapathy Al Thavaras Pathy, K. A. Khazali, Grant Wallace, Bruce Christie, Clive Battisby
In August 2020 the Operator deployed a fully immersive On The Rig (OTR) Simulator for the execution of a Drill the Well On Simulator (DWOS) project on the semi-submersible Maersk Developer to prepare the crew to drill the 1st Petronas Deepwater exploration well (name redacted to Well X) offshore Suriname. The offset well data showed numerous downhole troubled time events, such as well control and stuck pipe in addition to other risks that required to be actively managed. With many of the crew being new to the rig, competence was identified as a key risk. The Operator engaged a DWOS program to ensure the rig crew competence was accelerated and project risks were understood and mitigated. This was achieved through realistic simulations, well/rig specific training and advanced human factors training, specifically designed to ensure the successful delivery of the well.
{"title":"Mitigating Downhole Hazards and Improving Operational Performance using Advanced Human Performance Techniques and High-Fidelity Simulations","authors":"Kuhanesapathy Al Thavaras Pathy, K. A. Khazali, Grant Wallace, Bruce Christie, Clive Battisby","doi":"10.4043/31404-ms","DOIUrl":"https://doi.org/10.4043/31404-ms","url":null,"abstract":"\u0000 In August 2020 the Operator deployed a fully immersive On The Rig (OTR) Simulator for the execution of a Drill the Well On Simulator (DWOS) project on the semi-submersible Maersk Developer to prepare the crew to drill the 1st Petronas Deepwater exploration well (name redacted to Well X) offshore Suriname. The offset well data showed numerous downhole troubled time events, such as well control and stuck pipe in addition to other risks that required to be actively managed.\u0000 With many of the crew being new to the rig, competence was identified as a key risk. The Operator engaged a DWOS program to ensure the rig crew competence was accelerated and project risks were understood and mitigated. This was achieved through realistic simulations, well/rig specific training and advanced human factors training, specifically designed to ensure the successful delivery of the well.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"75874878","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}
Capital intensive industrial assets require highly specialized maintenance activities. Traditional preventive time-based approach, based on OEM maintenance policies, has been gradually evolving towards more sophisticated condition-based maintenance techniques. Further ISO 55000 states that assets exist to provide value to the organization and its stakeholders (BS ISO 55002, 2014). To develop a successful and modern maintenance program, it suggests having a value-based approach when dealing with maintenance decisions, both financial and non-financial constrains needs to be evaluated when decision taken regarding maintenance actions. Higher values can be reaped from an asset when the maintenance intervals are optimized. By optimization it is envisaged that the right number and type of maintenance tasks, at the right intervals, in the right way is performed on the asset to maximize the risk reduction within available budgetary constraints. The paper presents an overview of an analytics framework for predictive maintenance service boosted by Machine Learning and asset knowledge, applied to turbomachinery assets. Optimization of the maintenance scenario is performed through a risk model that assesses online health status and probability of failure, by detecting functional anomalies or aging phenomena and evaluating their impact on asset serviceability.
资本密集型工业资产需要高度专业化的维护活动。传统的基于时间的预防性方法(基于OEM维护政策)已逐渐演变为更复杂的基于状态的维护技术。此外，ISO 55000声明资产的存在是为了向组织及其利益相关者提供价值(BS ISO 55002, 2014)。为了制定一个成功的现代维护计划，它建议在处理维护决策时采用基于价值的方法，在做出有关维护行动的决策时，需要评估财务和非财务约束。当维护间隔得到优化时，可以从资产中获得更高的价值。通过优化，可以设想在适当的时间间隔内以正确的方式对资产执行正确数量和类型的维护任务，以在可用的预算限制内最大限度地降低风险。本文概述了一种基于机器学习和资产知识的预测性维护服务分析框架，并将其应用于涡轮机械资产。通过风险模型来优化维护场景，该模型通过检测功能异常或老化现象并评估其对资产可维护性的影响来评估在线健康状态和故障概率。
{"title":"Maintenance Scope Optimization, through a Real Time Prediction of Risk of Failure","authors":"Marzia Sepe, Gionata Ruggiero, Alessandro Leto, Gabriele Mordacci, Adolfo Agresta","doi":"10.4043/31343-ms","DOIUrl":"https://doi.org/10.4043/31343-ms","url":null,"abstract":"\u0000 Capital intensive industrial assets require highly specialized maintenance activities. Traditional preventive time-based approach, based on OEM maintenance policies, has been gradually evolving towards more sophisticated condition-based maintenance techniques. Further ISO 55000 states that assets exist to provide value to the organization and its stakeholders (BS ISO 55002, 2014). To develop a successful and modern maintenance program, it suggests having a value-based approach when dealing with maintenance decisions, both financial and non-financial constrains needs to be evaluated when decision taken regarding maintenance actions. Higher values can be reaped from an asset when the maintenance intervals are optimized. By optimization it is envisaged that the right number and type of maintenance tasks, at the right intervals, in the right way is performed on the asset to maximize the risk reduction within available budgetary constraints.\u0000 The paper presents an overview of an analytics framework for predictive maintenance service boosted by Machine Learning and asset knowledge, applied to turbomachinery assets. Optimization of the maintenance scenario is performed through a risk model that assesses online health status and probability of failure, by detecting functional anomalies or aging phenomena and evaluating their impact on asset serviceability.","PeriodicalId":11217,"journal":{"name":"Day 4 Fri, March 25, 2022","volume":"41 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2022-03-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79194871","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}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：