M. G. Mayani, R. Rommetveit, S. I. Oedegaard, Morten Svendsen
Having a Digital Twin of the drilling well, pairing digital and physical data combined with predictive analytics and diagnostic messages, improves accuracy in planning and decision making of the drilling operation. It helps the industry to increase safety, improve efficiency and gain the best economic-value-based decision as well as reduce operational cost. Today advanced monitoring is normally done using real-time measurements, compare pre-simulation results with measurements, perform manual diagnostics and run new simulations when abnormalities are seen. All done manually by people. Drilling can move beyond advanced monitoring using Digital Twin's by implementing automatic ‘forward-looking’ and multiple ‘what-if’ simulation to give operations the optimal plan with focus on safety, risk reduction and improved performance. The Digital Twin examples in the current paper can do more advanced and complex automatic forecasting simulations, diagnostics, ‘forward-looking’ and ‘what-if’ simulation as well as predictive analytics in the wellbore in the 2D and 3D simulation view. By using the advanced models (Digital Twin), all relevant challenges and risks were identified during the drilling operations of one well under high pressure high temperature (HPHT) conditions. The stand pipe pressure (SPP), equivalent circulating density (ECD) and temperature behavior were studied during the drilling and circulation of this well. The Digital Twin was also used to evaluate possible losses during 9 7/8″ casing running and cementing with special focus on when casing was passing through the formations. In another well the Digital Twin triggered an early notification regarding high cuttings concentration during drilling 8 ½″ section. The flow rate was adjusted and helped to prevent sidetrack and pack-off due to losses. Morover during drilling 17 ½″ section in another case, large losses were prevented by comparing the modeled active pit calculation and measured tank volume. The Digital Twin enables advanced automatic forecasting simulation, self-diagnostics, automatic ‘forward-looking’, multiple ‘what-if’ simulation and predictive analytics to improve safety, reduce risk, increase drilling performance and reduce costs.
{"title":"Drilling Automated Realtime Monitoring Using Digital Twin","authors":"M. G. Mayani, R. Rommetveit, S. I. Oedegaard, Morten Svendsen","doi":"10.2118/192807-MS","DOIUrl":"https://doi.org/10.2118/192807-MS","url":null,"abstract":"\u0000 Having a Digital Twin of the drilling well, pairing digital and physical data combined with predictive analytics and diagnostic messages, improves accuracy in planning and decision making of the drilling operation. It helps the industry to increase safety, improve efficiency and gain the best economic-value-based decision as well as reduce operational cost. Today advanced monitoring is normally done using real-time measurements, compare pre-simulation results with measurements, perform manual diagnostics and run new simulations when abnormalities are seen. All done manually by people.\u0000 Drilling can move beyond advanced monitoring using Digital Twin's by implementing automatic ‘forward-looking’ and multiple ‘what-if’ simulation to give operations the optimal plan with focus on safety, risk reduction and improved performance.\u0000 The Digital Twin examples in the current paper can do more advanced and complex automatic forecasting simulations, diagnostics, ‘forward-looking’ and ‘what-if’ simulation as well as predictive analytics in the wellbore in the 2D and 3D simulation view.\u0000 By using the advanced models (Digital Twin), all relevant challenges and risks were identified during the drilling operations of one well under high pressure high temperature (HPHT) conditions. The stand pipe pressure (SPP), equivalent circulating density (ECD) and temperature behavior were studied during the drilling and circulation of this well. The Digital Twin was also used to evaluate possible losses during 9 7/8″ casing running and cementing with special focus on when casing was passing through the formations. In another well the Digital Twin triggered an early notification regarding high cuttings concentration during drilling 8 ½″ section. The flow rate was adjusted and helped to prevent sidetrack and pack-off due to losses.\u0000 Morover during drilling 17 ½″ section in another case, large losses were prevented by comparing the modeled active pit calculation and measured tank volume. The Digital Twin enables advanced automatic forecasting simulation, self-diagnostics, automatic ‘forward-looking’, multiple ‘what-if’ simulation and predictive analytics to improve safety, reduce risk, increase drilling performance and reduce costs.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"29 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83650248","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}
To meet the regulations on the emission of toxic gases such as carbon monoxide (CO) and Hydrogen Sulfide (H2S) from the Sulphur Recovery Units (SRUs), a high amount of fuel gas is burnt in the incinerator to oxidize them that increases the sulfur production cost and CO2 emissions. This study investigates the major reactions that cause CO emissions and recommends possible solution to mitigate its formation in the SRU. The SRU simulations were conducted using a well validated and detailed reaction mechanism that captures the chemistry of CO and Sulfur species in the Claus furnace. The Claus reaction mechanism, containing 290 species and 1900 reversible reactions for the oxidation of H2S and the formation and destruction of COS, CO, CO2, hydrocarbons, and CS2 was used for reactor simulations, which was validated successfully using industrial plant data and the experimental data from lab-scale setups. The process parameters were varied to find the set of conditions that minimize CO production in the SRUs. The CO production in Claus furnace occurred through the high temperature decomposition of CO2 and CH4 present in the acid gas stream. The production of COS occurred from the reactions of CO with sulfur. The inlet temperatures of the feed gas streams (air and acid gas) were varied systematically to observe their effect on sulfur recovery and emissions of CO, SO2, COS, and aromatics. Upon decreasing the furnace temperature (by decreasing inlet air temperature) from 1105°C to 1050°C, CO emission from the SRU decreased by up to 60%, while sulfur recovery efficiency increased by 0.2%. However, the emission of aromatics (mainly benzene) increased by 3.5 ppm, while the more detrimental toluene, ethylbenzene and xylene were completely oxidized. Thus, maintaining an optimal feed temperature was found to minimize CO emissions from the SRUs, while maintaining high sulfur recovery. The simulation results predict the cost-effective solutions of minimizing CO and SO2 emissions from SRUs through the variation in process parameters that will help in reducing the consumption of fuel gas in the SRU incinerator.
{"title":"A Kinetic Simulation Study to Decrease Carbon Monoxide CO Emission from Sulfur Recovery Units SRU","authors":"S. Ibrahim, Ramees K. Rahman, A. Raj","doi":"10.2118/192771-MS","DOIUrl":"https://doi.org/10.2118/192771-MS","url":null,"abstract":"\u0000 To meet the regulations on the emission of toxic gases such as carbon monoxide (CO) and Hydrogen Sulfide (H2S) from the Sulphur Recovery Units (SRUs), a high amount of fuel gas is burnt in the incinerator to oxidize them that increases the sulfur production cost and CO2 emissions. This study investigates the major reactions that cause CO emissions and recommends possible solution to mitigate its formation in the SRU. The SRU simulations were conducted using a well validated and detailed reaction mechanism that captures the chemistry of CO and Sulfur species in the Claus furnace. The Claus reaction mechanism, containing 290 species and 1900 reversible reactions for the oxidation of H2S and the formation and destruction of COS, CO, CO2, hydrocarbons, and CS2 was used for reactor simulations, which was validated successfully using industrial plant data and the experimental data from lab-scale setups. The process parameters were varied to find the set of conditions that minimize CO production in the SRUs. The CO production in Claus furnace occurred through the high temperature decomposition of CO2 and CH4 present in the acid gas stream. The production of COS occurred from the reactions of CO with sulfur. The inlet temperatures of the feed gas streams (air and acid gas) were varied systematically to observe their effect on sulfur recovery and emissions of CO, SO2, COS, and aromatics. Upon decreasing the furnace temperature (by decreasing inlet air temperature) from 1105°C to 1050°C, CO emission from the SRU decreased by up to 60%, while sulfur recovery efficiency increased by 0.2%. However, the emission of aromatics (mainly benzene) increased by 3.5 ppm, while the more detrimental toluene, ethylbenzene and xylene were completely oxidized. Thus, maintaining an optimal feed temperature was found to minimize CO emissions from the SRUs, while maintaining high sulfur recovery. The simulation results predict the cost-effective solutions of minimizing CO and SO2 emissions from SRUs through the variation in process parameters that will help in reducing the consumption of fuel gas in the SRU incinerator.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"68 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"89864791","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 process of differentiating between rock volumes based on petrophysical properties and geological indicators is commonly referred to as rock typing. A rock type can be identified by a given porosity – permeability (k-Phi) transform and Saturation Height Model (SHM) in petrophysical space. Rock typing is a useful method by which geological interpretations are combined with petrophysical measurements and translated into physical space for use in subsurface modelling. Efforts here involve utilizing k-Phi transforms as an input to SHM, thereby streamlining the rock typing process and allowing for compatibility with existing rock typing workflows. A fundamental part of building realistic subsurface models includes populating a geologic framework with petrophysical properties. From a petrophysical point of view, critical properties with significant impact on the modelling outcome (hydrocarbon volumes recoverable and producibility) are hydrocarbon saturation, permeability and relative permeability. Hydrocarbon saturation is an expression of the rock capillarity translated into a mathematical expression from capillary pressure measurements or well log saturations. Permeability is commonly predicted from porosity, via transform equations used to differentiate reservoir rocks of different quality. Previous work has shown that permeability and SHM used for subsurface modelling are generally consistent. This implies that the number of input parameters to the SHM can be reduced, which can be done by integrating permeability and saturation data (from logs and core measurements). The number of parameters used in the predictive SHM is reduced from six to four. Here, we propose to constrain the entry pressure (responsible for hydrocarbon entry height) by using routine core analysis data. This approach aiming to look at the plug and log scale has significant benefits when a SHM is derived from well log saturation data or when a limited range in properties is sampled by capillary pressure measurements. The workflow allows the use of other permeability sources (like Drill Stem Test if representative of matrix) as starting point in the process of building a SHM via a simplified Brooks-Corey function. The function can be looked at as a hybrid between the Leverett's J and Brooks-Corey function with entry pressure dependency on the permeability to porosity ratio higher than for Leverett's J (0.7 vs 0.5). The result of linking k-Phi transforms to saturation height modelling allows for compatibility with multiple rock typing approaches that utilize different sorts of parameters to define k-Phi, including Lucia's classic rock fabric numbers, a useful benchmark.
根据岩石物理性质和地质指标区分岩石体积的过程通常被称为岩石分型。岩石物理空间中给定的孔隙度-渗透率(k-Phi)变换和饱和高度模型(SHM)可以识别岩石类型。岩石分型是一种有用的方法，通过这种方法，地质解释与岩石物理测量相结合，并转化为用于地下建模的物理空间。这里的工作包括利用k-Phi变换作为SHM的输入，从而简化岩石分型过程，并允许与现有岩石分型工作流程兼容。建立真实的地下模型的一个基本部分包括用岩石物理性质填充地质框架。从岩石物理学的角度来看，对建模结果(油气可采体积和产能)有重大影响的关键属性是油气饱和度、渗透率和相对渗透率。油气饱和度是将岩石毛细作用转化为毛细压力测量或测井饱和度的数学表达式。渗透率通常由孔隙度预测，通过转换方程来区分不同质量的储层岩石。以前的工作表明，用于地下建模的渗透率和SHM通常是一致的。这意味着SHM输入参数的数量可以减少，这可以通过整合渗透率和饱和度数据(来自测井和岩心测量)来实现。在预测SHM中使用的参数数量从6个减少到4个。在这里，我们建议使用常规岩心分析数据来限制进入压力(负责油气进入高度)。当从测井饱和度数据中得出SHM，或者通过毛细管压力测量采样有限的属性范围时，这种旨在观察桥塞和测井尺度的方法具有显著的优势。该工作流程允许使用其他渗透率源(如钻杆测试，如果代表矩阵)作为通过简化的Brooks-Corey函数构建SHM过程的起点。该函数可以看作是Leverett的J函数和Brooks-Corey函数的混合体，其进入压力依赖于渗透率与孔隙度比高于Leverett的J函数(0.7 vs 0.5)。将k-Phi转换到饱和高度建模的结果允许与多种岩石类型方法兼容，这些方法使用不同类型的参数来定义k-Phi，包括Lucia的经典岩石结构数，这是一个有用的基准。
{"title":"A Method to Obtain a Permeability - Constrained and Consistent Saturation Height Model","authors":"I. Hulea","doi":"10.2118/193164-MS","DOIUrl":"https://doi.org/10.2118/193164-MS","url":null,"abstract":"\u0000 The process of differentiating between rock volumes based on petrophysical properties and geological indicators is commonly referred to as rock typing. A rock type can be identified by a given porosity – permeability (k-Phi) transform and Saturation Height Model (SHM) in petrophysical space. Rock typing is a useful method by which geological interpretations are combined with petrophysical measurements and translated into physical space for use in subsurface modelling. Efforts here involve utilizing k-Phi transforms as an input to SHM, thereby streamlining the rock typing process and allowing for compatibility with existing rock typing workflows.\u0000 A fundamental part of building realistic subsurface models includes populating a geologic framework with petrophysical properties. From a petrophysical point of view, critical properties with significant impact on the modelling outcome (hydrocarbon volumes recoverable and producibility) are hydrocarbon saturation, permeability and relative permeability. Hydrocarbon saturation is an expression of the rock capillarity translated into a mathematical expression from capillary pressure measurements or well log saturations. Permeability is commonly predicted from porosity, via transform equations used to differentiate reservoir rocks of different quality.\u0000 Previous work has shown that permeability and SHM used for subsurface modelling are generally consistent. This implies that the number of input parameters to the SHM can be reduced, which can be done by integrating permeability and saturation data (from logs and core measurements). The number of parameters used in the predictive SHM is reduced from six to four. Here, we propose to constrain the entry pressure (responsible for hydrocarbon entry height) by using routine core analysis data. This approach aiming to look at the plug and log scale has significant benefits when a SHM is derived from well log saturation data or when a limited range in properties is sampled by capillary pressure measurements. The workflow allows the use of other permeability sources (like Drill Stem Test if representative of matrix) as starting point in the process of building a SHM via a simplified Brooks-Corey function. The function can be looked at as a hybrid between the Leverett's J and Brooks-Corey function with entry pressure dependency on the permeability to porosity ratio higher than for Leverett's J (0.7 vs 0.5). The result of linking k-Phi transforms to saturation height modelling allows for compatibility with multiple rock typing approaches that utilize different sorts of parameters to define k-Phi, including Lucia's classic rock fabric numbers, a useful benchmark.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90291544","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
F. Cailly, T. Al-Romani, C. Hubans, A. Lafram, A. Kaabi
This paper describes 4D interpretation results in a very challenging Middle East carbonate context. It consists of a 4D pilot (OBC/OBC) over a giant field divided into two phases. For Phase1 the monitor seismic survey has repeated the geometry of the base survey (parallel shooting) to get started in the best possible 4D conditions. For Phase2 the monitor seismic survey design is a modern source spread acquisition for wide azimuth objective. It is clearly different from the base survey design, and so starts with a worse 4D repeatibility. In this paper, we describe the challenges attached to both phases of this pilot and explain how in the end it has been successfully interpreted. A focused study is made on a particular 4D anomaly corresponding to an increase of impedance in the reservoir. This is interpreted as the water front movement (due to water injection) during the interval between base and monitor surveys. Petrophysically this is consistent, if water replaces oil in the reservoir then impedance increases. However, 4D interpretation can be ambiguous and other production phenomena can explain impedance increase, so the interpretation must be assessed carefully. This is done through calibration of the interpretation to well data (time evolution of the water cut). The final interpretation is robust. Other elements not described in the paper could have been added to consolidate the interpretation like the fact that interpreted 4D anomalies (and so water rise-up) stop vertically on a well known impermeable barrier (anhydrite level). Once the 4D signal is calibrated, unexpected phenomena (i.e. heterogeneities not predicted by the reservoir model) are highlighted as potentially providing added value to reservoir understanding. As a deliverable, 4D anomalies are interpreted as 3D geobodies and a water rise-up top surface is picked. This information will be key to position new wells and to update the reservoir model. Though 4D seismic techniques are very mature and widely illustrated in clastic reservoir environments, it is still rarely used operationally to monitor carbonate fields. This paper proves the concept that a reliable 4D signal can be extracted over such Middle-East carbonate reservoir.
{"title":"A Successful 4D Seismic Monitoring in Middle-East Carbonate Reservoir Context","authors":"F. Cailly, T. Al-Romani, C. Hubans, A. Lafram, A. Kaabi","doi":"10.2118/193063-MS","DOIUrl":"https://doi.org/10.2118/193063-MS","url":null,"abstract":"\u0000 This paper describes 4D interpretation results in a very challenging Middle East carbonate context.\u0000 It consists of a 4D pilot (OBC/OBC) over a giant field divided into two phases. For Phase1 the monitor seismic survey has repeated the geometry of the base survey (parallel shooting) to get started in the best possible 4D conditions. For Phase2 the monitor seismic survey design is a modern source spread acquisition for wide azimuth objective. It is clearly different from the base survey design, and so starts with a worse 4D repeatibility.\u0000 In this paper, we describe the challenges attached to both phases of this pilot and explain how in the end it has been successfully interpreted.\u0000 A focused study is made on a particular 4D anomaly corresponding to an increase of impedance in the reservoir. This is interpreted as the water front movement (due to water injection) during the interval between base and monitor surveys. Petrophysically this is consistent, if water replaces oil in the reservoir then impedance increases. However, 4D interpretation can be ambiguous and other production phenomena can explain impedance increase, so the interpretation must be assessed carefully. This is done through calibration of the interpretation to well data (time evolution of the water cut).\u0000 The final interpretation is robust. Other elements not described in the paper could have been added to consolidate the interpretation like the fact that interpreted 4D anomalies (and so water rise-up) stop vertically on a well known impermeable barrier (anhydrite level).\u0000 Once the 4D signal is calibrated, unexpected phenomena (i.e. heterogeneities not predicted by the reservoir model) are highlighted as potentially providing added value to reservoir understanding. As a deliverable, 4D anomalies are interpreted as 3D geobodies and a water rise-up top surface is picked. This information will be key to position new wells and to update the reservoir model.\u0000 Though 4D seismic techniques are very mature and widely illustrated in clastic reservoir environments, it is still rarely used operationally to monitor carbonate fields. This paper proves the concept that a reliable 4D signal can be extracted over such Middle-East carbonate reservoir.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"64 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90331999","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}
Maniesh Singh, Khaleefa Al Benali, Y. Sallam, Kashif Sajeel, Fathy ElWazeer, H. A. Chaker, Maarten Propper
The ability to measure formation petro physical properties thru drillpipe has always been a challenge. It requires unconventional approaches to remove the effects of metal and borehole fluids on both the transmitted and received logging signals. This paper will present a proven technology executed in more than 1,000 wells all over the world and a first two successful trail case study from ADNOC Onshore wells in the Middle East. The main objective is to acquire triple combo data (resistivity, density, neutron, gamma ray, spectral gamma ray & caliper) using the LWT conveyance and acquisition technology where there is a high risk of downhole triple combo Logging While Drilling (LWD) and or wireline (WL) tools getting stuck and the risk of losing radioactive sources. The new patent pending technique was executed by using a slim downhole measurement tools inside specially designed drill collars invisible to the measurement sensors. LWT collars can be used for drilling and reaming as with normal drill collars. Propagation resistivity and neutron measurements are mostly like conventional techniques in tools physics. Density and nuclear caliper are measured by modelling the responses of three detectors short, medium and long distance away from the cesium source. The measured LWT log data has been validated through back to back comparisons with WL & LWD) logs showing almost one to one correlation considering the effects of mud invasion due to lapsed time between runs, different wellbore condition and different depth of investigations. Measured caliper, resistivity, density, neutron from LWT showed respectable match with WL or LWD tool. The differences in log responses are explained by differences in tool physics, logging speeds and environmental conditions. Similarly, the computed porosity from LWT tool comparison with WL and LWT porosity has almost the same statistics. The Quality LWT data was acquired in both wells at virtually zero LIH risk and minimum extra drilling rig time. Introducing the new LWT technique to measure accurate Open Hole formation evaluation data from inside the drill-string is a cost-effective solution in various challenging scenarios, Exploratory/ Appraisal/ Development risky & challenging wells with unknown reservoir pressures or unsystematic depletion scenarios, complex downhole in-situ stress regimes, challenging tectonically faulted or fractured areas & unstable shales and many more, posing challenge to drill stable holes and a threat to LWD/ WL radioactive tool stuck.Unplanned deviated 8-1/2’ hole section geo-steered by MWD-GR, where at last minute triple combo is desired.
{"title":"A Case Study on Open-Hole Logging While Tripping LWT Through Drill Pipes, as a New Technology for Risk Mitigation and Cost Optimization in Abu Dhabi Onshore Fields","authors":"Maniesh Singh, Khaleefa Al Benali, Y. Sallam, Kashif Sajeel, Fathy ElWazeer, H. A. Chaker, Maarten Propper","doi":"10.2118/193315-MS","DOIUrl":"https://doi.org/10.2118/193315-MS","url":null,"abstract":"\u0000 The ability to measure formation petro physical properties thru drillpipe has always been a challenge. It requires unconventional approaches to remove the effects of metal and borehole fluids on both the transmitted and received logging signals. This paper will present a proven technology executed in more than 1,000 wells all over the world and a first two successful trail case study from ADNOC Onshore wells in the Middle East.\u0000 The main objective is to acquire triple combo data (resistivity, density, neutron, gamma ray, spectral gamma ray & caliper) using the LWT conveyance and acquisition technology where there is a high risk of downhole triple combo Logging While Drilling (LWD) and or wireline (WL) tools getting stuck and the risk of losing radioactive sources.\u0000 The new patent pending technique was executed by using a slim downhole measurement tools inside specially designed drill collars invisible to the measurement sensors. LWT collars can be used for drilling and reaming as with normal drill collars. Propagation resistivity and neutron measurements are mostly like conventional techniques in tools physics. Density and nuclear caliper are measured by modelling the responses of three detectors short, medium and long distance away from the cesium source.\u0000 The measured LWT log data has been validated through back to back comparisons with WL & LWD) logs showing almost one to one correlation considering the effects of mud invasion due to lapsed time between runs, different wellbore condition and different depth of investigations.\u0000 Measured caliper, resistivity, density, neutron from LWT showed respectable match with WL or LWD tool. The differences in log responses are explained by differences in tool physics, logging speeds and environmental conditions. Similarly, the computed porosity from LWT tool comparison with WL and LWT porosity has almost the same statistics. The Quality LWT data was acquired in both wells at virtually zero LIH risk and minimum extra drilling rig time.\u0000 Introducing the new LWT technique to measure accurate Open Hole formation evaluation data from inside the drill-string is a cost-effective solution in various challenging scenarios, Exploratory/ Appraisal/ Development risky & challenging wells with unknown reservoir pressures or unsystematic depletion scenarios, complex downhole in-situ stress regimes, challenging tectonically faulted or fractured areas & unstable shales and many more, posing challenge to drill stable holes and a threat to LWD/ WL radioactive tool stuck.Unplanned deviated 8-1/2’ hole section geo-steered by MWD-GR, where at last minute triple combo is desired.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"94 10 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"91086266","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}
Y. Al-Aufi, Al Salt Malik Al Sulti, A. Arnaout, Sara Bakhti, G. Thonhauser
Digital transformation is a process of applying all digital technologies on current workflows to be able to deliver high quality information at the right time. Improving well delivery time is one of the goals for applying digital transformation inside the company. The drilling performance should be reported on daily basis and all the drifting from predefined targets should be spotted and reported directly. Hence, the drilling crews require more detailed information of their performance, to proactively develop best practices and improve efficiency. Drilling process digitalization is one of the tools that has significant impact to achieve this goal. This was initially started inside the operating company to implement advanced digitalization technologies to monitoring and improvement drilling operations and to follow up drilling contractors through their digital footprints on the operational performance. The advances in digital technologies and tools provide enable measuring rig activities through real-time rig sensor data and merge it with other information sources. Therefore, a setup of a real-time digitalization tool based on automated rig activities detection technology is established and a measurement and monitoring process was started. The results of the digitalization process, after an initial evaluation period of approximately 1 month, exposed the savings potential by identifying Invisible Lost Time (ILT). As an example, the result of applying this agile and collaborative process, an improvement of "Weight to Weight" times between 45% and respectively 25% was achieved for two rigs, which reflects an actual saving up to 7% of the total well delivery time. The drilling team achieved measurable savings equal to one average total well duration in the one year of operation.
{"title":"The Impact of Digital Transformation on Cutting Drilling Costs - A Case Study from Oman","authors":"Y. Al-Aufi, Al Salt Malik Al Sulti, A. Arnaout, Sara Bakhti, G. Thonhauser","doi":"10.2118/193198-MS","DOIUrl":"https://doi.org/10.2118/193198-MS","url":null,"abstract":"\u0000 Digital transformation is a process of applying all digital technologies on current workflows to be able to deliver high quality information at the right time. Improving well delivery time is one of the goals for applying digital transformation inside the company. The drilling performance should be reported on daily basis and all the drifting from predefined targets should be spotted and reported directly. Hence, the drilling crews require more detailed information of their performance, to proactively develop best practices and improve efficiency. Drilling process digitalization is one of the tools that has significant impact to achieve this goal.\u0000 This was initially started inside the operating company to implement advanced digitalization technologies to monitoring and improvement drilling operations and to follow up drilling contractors through their digital footprints on the operational performance. The advances in digital technologies and tools provide enable measuring rig activities through real-time rig sensor data and merge it with other information sources. Therefore, a setup of a real-time digitalization tool based on automated rig activities detection technology is established and a measurement and monitoring process was started.\u0000 The results of the digitalization process, after an initial evaluation period of approximately 1 month, exposed the savings potential by identifying Invisible Lost Time (ILT). As an example, the result of applying this agile and collaborative process, an improvement of \"Weight to Weight\" times between 45% and respectively 25% was achieved for two rigs, which reflects an actual saving up to 7% of the total well delivery time. The drilling team achieved measurable savings equal to one average total well duration in the one year of operation.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"27 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78154944","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}
Enhancements the performance of Rotating Equipment in term of cost optimization by extending the MTBI and improving the efficiency is dynamic exercises and endless journey, so by utilizing the proven available latest technology to protect the gas turbines from fouling is the Operator major challenge. The Air Inlet Filtration System is a very important auxiliary system protecting Gas Turbine (GT) internal components from air born contaminants at reasonable pressure drop (PD) Enhancements the performance of Rotating Equipment in term of cost optimization by extending the MTBI and improving the efficiency is dynamic exercises and endless journey, so by utilizing the proven available latest technology to protect the gas turbines from fouling. The Air Inlet Filtration System is a very important auxiliary system protecting Gas Turbine (GT) internal components from air born contaminants at reasonable pressure drop (PD) Turbine Inlet Air Filtration System utilizing "D-Fog + F9 Pulse Jet + HEPA-E12 Static Filter is a reality of improvement/Saving by actual readings from PI System of gas turbines leading to achieved the followings within filter service Life Time (Two Years) : GTs filtration system upgrades are considered as standard for all Single Stage Self Cleaning Filtration as well as multistage Filtration system and as a good reference in case for other entities within ADNOC group of Companies to follow and achieve similar benefits as applicable for their Gas Turbines applications, since ADNOC -OPCOs have big fleets of Gas Turbines to gain all benefits mentioned. The initiative of "Improving the Quality of Gas Turbine Inlet Air via upgrading the Filter Element to HEPA12/E12 class media type as a direct replacement to the installed (D-Fog + F8 Pulse Jet class + F9 Static) and upgraded to "D-Fog + F9 Pulse Jet + HEPA-E12 Static had been achieved
{"title":"Air Filtration - The Dark Horse of Gas Turbine Performance","authors":"Shahin Abdel Samad Shahin Elsawy","doi":"10.2118/193251-MS","DOIUrl":"https://doi.org/10.2118/193251-MS","url":null,"abstract":"\u0000 \u0000 \u0000 Enhancements the performance of Rotating Equipment in term of cost optimization by extending the MTBI and improving the efficiency is dynamic exercises and endless journey, so by utilizing the proven available latest technology to protect the gas turbines from fouling is the Operator major challenge.\u0000 The Air Inlet Filtration System is a very important auxiliary system protecting Gas Turbine (GT) internal components from air born contaminants at reasonable pressure drop (PD)\u0000 \u0000 \u0000 \u0000 Enhancements the performance of Rotating Equipment in term of cost optimization by extending the MTBI and improving the efficiency is dynamic exercises and endless journey, so by utilizing the proven available latest technology to protect the gas turbines from fouling.\u0000 The Air Inlet Filtration System is a very important auxiliary system protecting Gas Turbine (GT) internal components from air born contaminants at reasonable pressure drop (PD)\u0000 \u0000 \u0000 \u0000 Turbine Inlet Air Filtration System utilizing \"D-Fog + F9 Pulse Jet + HEPA-E12 Static Filter is a reality of improvement/Saving by actual readings from PI System of gas turbines leading to achieved the followings within filter service Life Time (Two Years) :\u0000 GTs filtration system upgrades are considered as standard for all Single Stage Self Cleaning Filtration as well as multistage Filtration system and as a good reference in case for other entities within ADNOC group of Companies to follow and achieve similar benefits as applicable for their Gas Turbines applications, since ADNOC -OPCOs have big fleets of Gas Turbines to gain all benefits mentioned.\u0000 \u0000 \u0000 \u0000 The initiative of \"Improving the Quality of Gas Turbine Inlet Air via upgrading the Filter Element to HEPA12/E12 class media type as a direct replacement to the installed (D-Fog + F8 Pulse Jet class + F9 Static) and upgraded to \"D-Fog + F9 Pulse Jet + HEPA-E12 Static had been achieved\u0000","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"44 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77394153","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}
Inspection intervals have been long established in some jurisdictions around the world based on an assessment of acceptable risk from experience, judgment, and observations of past damage. In areas that do not have the benefit of decades of experience, the designated inspection intervals may be inheriting intervals from another region of the world, and in doing so, potentially subscribing to inspection interval frequencies that assume less or more risk than has been deemed acceptable in other areas of the world. This study investigates two prototype steel piled jacket platforms subjected to metocean conditions present in several areas of offshore development around the world, with the objective to investigate the relative fatigue performance of the prototype structures in these varied environments. The relative performance of these various locations may lend insight into the implementation of risk-consistent inspection intervals for structural integrity maintenance programs.
{"title":"Risk-Adjusted Underwater Inspection Intervals for Steel Piled Jackets","authors":"R. Foltz, A. Younan","doi":"10.2118/193206-MS","DOIUrl":"https://doi.org/10.2118/193206-MS","url":null,"abstract":"\u0000 Inspection intervals have been long established in some jurisdictions around the world based on an assessment of acceptable risk from experience, judgment, and observations of past damage. In areas that do not have the benefit of decades of experience, the designated inspection intervals may be inheriting intervals from another region of the world, and in doing so, potentially subscribing to inspection interval frequencies that assume less or more risk than has been deemed acceptable in other areas of the world. This study investigates two prototype steel piled jacket platforms subjected to metocean conditions present in several areas of offshore development around the world, with the objective to investigate the relative fatigue performance of the prototype structures in these varied environments. The relative performance of these various locations may lend insight into the implementation of risk-consistent inspection intervals for structural integrity maintenance programs.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"309 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73752276","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}
N. Diaz, Phalgun Paila, C. Kirby, B. Akl, Dalia Mahmoud, Rashid Khudaim Al Kindi, Youssef Kasem, Mhammed Benygzer, M. Haddad, V. Leon
Directional drilling from artificial islands has become a common offshore practice in the United Arab Emirates, looking to minimize footprint while optimizing cost to reach maximum number of targets from a single location. This drilling practice brings some challenges such as torque and drag limitations, which is vital in order to safely reach wells total depth in well profiles with a high departure. The purpose of this paper is to discuss in detail the successful implementation of torque reduction techniques, focused on case histories from an artificial offshore island in the United Arab Emirates. During the planning phase, Drilling Engineers estimate expected torque and drag for the different sections based on modeling and historical data, this process is key to assess the limitations and initiate the process of evaluating the different torque and drag reduction techniques to be implemented based on the application. The case histories presented in this paper show the successful implementation of proven torque and drag management techniques, such as; well profile optimization, torque reduction subs, deployment of lubricated mud, use of real-time directional data to minimize hole tortuosity, and deployment of Rotary Steerable Systems from top to bottom for improved hole quality. There are different factors considered in the planning phase that make torque and drag management crucial, but drill pipes torque limitation was the main challenge to overcome in order to reach planned total depth in the case histories discussed in this paper. Wells trajectory and BHA optimization played an important role during the execution phase, as well as the deployment of lubricated mud and torque reduction subs which in conjunction provided an overall surface torque reduction of up to 28%. The implementation of different torque and drag reduction methods are illustrated with the modeling results and actual drilling data collected during the drilling of these wells. Information and data discussed in this paper can serve as documentation to aid in the planning phase for wells with similar challenges.
{"title":"Successful Implementation of Torque and Drag Management Techniques in High Departure Wells is the Key to Safely Reach Wells Planned Total Depth in Offshore Artificial Islands","authors":"N. Diaz, Phalgun Paila, C. Kirby, B. Akl, Dalia Mahmoud, Rashid Khudaim Al Kindi, Youssef Kasem, Mhammed Benygzer, M. Haddad, V. Leon","doi":"10.2118/192709-MS","DOIUrl":"https://doi.org/10.2118/192709-MS","url":null,"abstract":"\u0000 Directional drilling from artificial islands has become a common offshore practice in the United Arab Emirates, looking to minimize footprint while optimizing cost to reach maximum number of targets from a single location. This drilling practice brings some challenges such as torque and drag limitations, which is vital in order to safely reach wells total depth in well profiles with a high departure. The purpose of this paper is to discuss in detail the successful implementation of torque reduction techniques, focused on case histories from an artificial offshore island in the United Arab Emirates.\u0000 During the planning phase, Drilling Engineers estimate expected torque and drag for the different sections based on modeling and historical data, this process is key to assess the limitations and initiate the process of evaluating the different torque and drag reduction techniques to be implemented based on the application. The case histories presented in this paper show the successful implementation of proven torque and drag management techniques, such as; well profile optimization, torque reduction subs, deployment of lubricated mud, use of real-time directional data to minimize hole tortuosity, and deployment of Rotary Steerable Systems from top to bottom for improved hole quality.\u0000 There are different factors considered in the planning phase that make torque and drag management crucial, but drill pipes torque limitation was the main challenge to overcome in order to reach planned total depth in the case histories discussed in this paper. Wells trajectory and BHA optimization played an important role during the execution phase, as well as the deployment of lubricated mud and torque reduction subs which in conjunction provided an overall surface torque reduction of up to 28%.\u0000 The implementation of different torque and drag reduction methods are illustrated with the modeling results and actual drilling data collected during the drilling of these wells. Information and data discussed in this paper can serve as documentation to aid in the planning phase for wells with similar challenges.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"24 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"72659749","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}
L. Phillips, Andrew Morris, G. Innes, Adrian Clark, Pierre-Marie Hinden
This paper highlights the value associated with the thermal processing of drill cuttings offshore, at source, on an operational and economic basis for a single well drilling campaign. Treating materials at source eliminates the requirement to transport drilling wastes long distances onshore for treatment and/or disposal, significantly reducing logistics costs and the likelihood of safety and environmental incidents. The paper outlines a safe, efficient and reliable at source drilling waste management solution that increases operational efficiency, supports well cost reduction initiatives and exceeds regulatory requirements. It also demonstrates that mobilizing this solution as an onboard drill cuttings processing spread for a one- well drilling campaign is cost-effective. The paper draws on a detailed case study in which thermal drill cuttings processing technology was mobilized for a one-well drilling campaign on the Orlando field in the UK North Sea, under a contract between TWMA and the Licence Operator but managed by the Well Operator AGR Well Management (AGR). Using a process of thermal desorption, the solution allows the recovery of three elements from the drill cuttings: oil, water and solids. Recovered base oil, which retains its full original quality, can be reintroduced to the drilling mud system, and recovered water and solids can be safely dispersed on location as they are processed to well within UK environmental tolerances and regulatory requirements. Using the technology on the Orlando development well enabled a reduction in drilling waste handling and reduced downtime, due to the elimination of wait on weather, reducing rig non-productive time by allowing continuous drilling during adverse weather conditions. It also reduced handling, storage, offshore lifting and skip to shore vessel requirements, for the 17 ½" and 12 ½" sections, saving an estimated $640,000 in vessel costs alone (based on the market rates at that time). Thorough planning meant initial challenges relating to delivery of equipment was quickly mitigated and support from TWMA, in close co-operation with AGR and the operator, helped to reduce the operational time-table and costs. The drilling waste management operation was completed within time and on budget with zero Lost Time Incidents and zero loss of containment to the environment during operations.
{"title":"Drilling Waste Management – Solutions that Optimise Drilling, Reduce Well Cost and Improve Environmental Performance","authors":"L. Phillips, Andrew Morris, G. Innes, Adrian Clark, Pierre-Marie Hinden","doi":"10.2118/192793-MS","DOIUrl":"https://doi.org/10.2118/192793-MS","url":null,"abstract":"\u0000 This paper highlights the value associated with the thermal processing of drill cuttings offshore, at source, on an operational and economic basis for a single well drilling campaign.\u0000 Treating materials at source eliminates the requirement to transport drilling wastes long distances onshore for treatment and/or disposal, significantly reducing logistics costs and the likelihood of safety and environmental incidents.\u0000 The paper outlines a safe, efficient and reliable at source drilling waste management solution that increases operational efficiency, supports well cost reduction initiatives and exceeds regulatory requirements.\u0000 It also demonstrates that mobilizing this solution as an onboard drill cuttings processing spread for a one- well drilling campaign is cost-effective.\u0000 The paper draws on a detailed case study in which thermal drill cuttings processing technology was mobilized for a one-well drilling campaign on the Orlando field in the UK North Sea, under a contract between TWMA and the Licence Operator but managed by the Well Operator AGR Well Management (AGR).\u0000 Using a process of thermal desorption, the solution allows the recovery of three elements from the drill cuttings: oil, water and solids. Recovered base oil, which retains its full original quality, can be reintroduced to the drilling mud system, and recovered water and solids can be safely dispersed on location as they are processed to well within UK environmental tolerances and regulatory requirements. Using the technology on the Orlando development well enabled a reduction in drilling waste handling and reduced downtime, due to the elimination of wait on weather, reducing rig non-productive time by allowing continuous drilling during adverse weather conditions. It also reduced handling, storage, offshore lifting and skip to shore vessel requirements, for the 17 ½\" and 12 ½\" sections, saving an estimated $640,000 in vessel costs alone (based on the market rates at that time).\u0000 Thorough planning meant initial challenges relating to delivery of equipment was quickly mitigated and support from TWMA, in close co-operation with AGR and the operator, helped to reduce the operational time-table and costs.\u0000 The drilling waste management operation was completed within time and on budget with zero Lost Time Incidents and zero loss of containment to the environment during operations.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"36 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74550351","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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