E. BinAbadat, H. Bu-Hindi, C. Lehmann, Atul Kumar, H. Al-Harbi, A. Al-Ali, Adel Al Katheeri
In this study, core and log data were integrated to identify intervals which are rich in stromatoporoids in an Upper Jurassic carbonate reservoir of an offshore green field Abu Dhabi. The main objective of this study was to recognize and stromatoporoids floatstones/rudstones in core, and develop criteria and workflow to identify them in uncored wells using borehole images. The following workflow was used during this study: i) Identification of the stromatoporoid feature in pilot wells with core and borehole images, ii) Investigate the properties and architecture of stromatoporoid bodies, iii) Integrate the same scale of core observations with borehole images and conventional log data (gamma ray, neutron porosity and bulk density logs) to identify stromatoporoid-rich layers, iv) Performing a blind test on a well by using the criteria developed from previous steps to identify "stromatoporoid accumulations" on a borehole image, and validate it with core observations. In the reservoir under investgation, stromatoporoid floatstones/rudstones intervals were identified and recognized both on core and borehole image in the pilot wells. These distinct reservoir bodies of stromatoporoids commonly occur in upper part of the reservoir and can reach to a thickness of around 20ft. The distribution and thickness of stromatoporoid bodies as well as growth forms (massive versus branching) were recognized on core and borehole images. The accumulations varied between massive beds of containing large pieces of stromatoporoids and grainstone beds rich in stromatoporoid debris. The massive beds of stromatoporoid accumulations are well developed in the northern part of the field. These layers can enhance the reservoir quality because of their distinct vuggy porosity and permeability that can reach up to several hundred of milidarcies (mD). Therefore, it is important to capture stromatoporoid layers both vertically and laterally in the static and dynamic model. Integrating borehole image data with core data and developing a workflow to identify stromatoporoid intervals in uncored wells is crucial to our subsurface understanding and will help to understand reservoir performance. Integration of image log data which is calibrated to core and log data proved to be critical in generating reservoir facies maps and correlations, which were integrated into a sequence stratigraphic framework as well. The results were used in the static model in distribution of high permeability layers related to the distribution of stromatoporoids.
{"title":"A Workflow to Integrate Core and Image Logs in Order to Enhance the Characterization of Subsurface Facies on Carbonate Reservoirs, Offshore Abu Dhabi","authors":"E. BinAbadat, H. Bu-Hindi, C. Lehmann, Atul Kumar, H. Al-Harbi, A. Al-Ali, Adel Al Katheeri","doi":"10.2118/193192-MS","DOIUrl":"https://doi.org/10.2118/193192-MS","url":null,"abstract":"\u0000 In this study, core and log data were integrated to identify intervals which are rich in stromatoporoids in an Upper Jurassic carbonate reservoir of an offshore green field Abu Dhabi. The main objective of this study was to recognize and stromatoporoids floatstones/rudstones in core, and develop criteria and workflow to identify them in uncored wells using borehole images.\u0000 The following workflow was used during this study: i) Identification of the stromatoporoid feature in pilot wells with core and borehole images, ii) Investigate the properties and architecture of stromatoporoid bodies, iii) Integrate the same scale of core observations with borehole images and conventional log data (gamma ray, neutron porosity and bulk density logs) to identify stromatoporoid-rich layers, iv) Performing a blind test on a well by using the criteria developed from previous steps to identify \"stromatoporoid accumulations\" on a borehole image, and validate it with core observations.\u0000 In the reservoir under investgation, stromatoporoid floatstones/rudstones intervals were identified and recognized both on core and borehole image in the pilot wells. These distinct reservoir bodies of stromatoporoids commonly occur in upper part of the reservoir and can reach to a thickness of around 20ft. The distribution and thickness of stromatoporoid bodies as well as growth forms (massive versus branching) were recognized on core and borehole images. The accumulations varied between massive beds of containing large pieces of stromatoporoids and grainstone beds rich in stromatoporoid debris. The massive beds of stromatoporoid accumulations are well developed in the northern part of the field. These layers can enhance the reservoir quality because of their distinct vuggy porosity and permeability that can reach up to several hundred of milidarcies (mD). Therefore, it is important to capture stromatoporoid layers both vertically and laterally in the static and dynamic model. Integrating borehole image data with core data and developing a workflow to identify stromatoporoid intervals in uncored wells is crucial to our subsurface understanding and will help to understand reservoir performance.\u0000 Integration of image log data which is calibrated to core and log data proved to be critical in generating reservoir facies maps and correlations, which were integrated into a sequence stratigraphic framework as well. The results were used in the static model in distribution of high permeability layers related to the distribution of stromatoporoids.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"2 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90370949","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}
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}
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}
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}
Ivy Chai Ching Hsia, Nur Anisah Shafie, N. Razali, A. A. A. Manap, I. K. Salleh
The application chemicals such as surfactants for Enhanced Oil Recovery (EOR) has caught the attention of various stakeholders especially regulators and operators - raising concerns of the impact of these chemicals to the ocean when they are back-produced. The current approach in mitigating the toxicity at production is the dilution of produced fluids to a lower concentration before disposal to sea. However, how confident are we that EOR chemicals do not cause environmental impact to marine life? Due diligence conducted showed that there are no environmental regulations or guidelines in Malaysia for the application of EOR chemicals at an offshore platform. For this reason, our team refers to the strictest of regulation for chemicals' use and discharge for an offshore environment used at the North/Norwegian Sea, adopting all qualification criteria from Harmonized Ocean Chemical Notification Format (HOCNF), of the OSPAR Harmonised Mandatory Control System (HMCS), developed through the OSPAR Decision 2000/2. HOCNF ranks chemical products according to Hazard Quotient (HQ), calculated using the Chemical Hazard and Risk Management (CHARM) model. CHARM is a set of rules to determine the risk and extent of surfactant formulation's movement in the ocean - a vital decision making tool to determine if EOR chemicals are safe for use and overboard discharge. This paper describes the ‘environmental-friendliness’ of a newly developed surfactant formulation which will be applied in a Water-Alternating-Gas (WAG) operation at an offshore field in Malaysia using CHARM. First, a comprehensive review of the components of the formulation was conducted, leading to sound selection and/or synthesis of chemistries that confers good environmental properties i.e. non- or low toxicity, persistency, bioaccumulation, with high biodegradability. Next was to determine the degree of toxicity of the formulation at three trophic levels. Using the lowest acute toxicity value, we apply this value to the CHARM model to calculate the dilution of the formulation 500 m radius from the point of discharge - given the expected adsorption, application concentration, and the volume ratio between squeeze vs. produced water. Whether CHARM is exhaustive to decide if the surfactant formulation can be discharged overboard is still being debated. Many argued that it is the responsibility of the chemical manufacturer or product inventor to select or synthesize chemistries with good ecotoxicity properties in the first place. Product innovation has to be aware on new regulation(s) e.g. the banning on the use of a chemical currently used in manufacturing so that the company develops an alternative ahead of its competitors. In the operator's viewpoint, even if the model indicates that the chemical pose a low hazard, physicochemical parameters of the produced fluids has to be monitored beyond the pilot implementation period.
{"title":"Using CHARM Modelling to Decide the use and Discharge of Surfactant at an Offshore EOR Project","authors":"Ivy Chai Ching Hsia, Nur Anisah Shafie, N. Razali, A. A. A. Manap, I. K. Salleh","doi":"10.2118/192715-MS","DOIUrl":"https://doi.org/10.2118/192715-MS","url":null,"abstract":"\u0000 The application chemicals such as surfactants for Enhanced Oil Recovery (EOR) has caught the attention of various stakeholders especially regulators and operators - raising concerns of the impact of these chemicals to the ocean when they are back-produced. The current approach in mitigating the toxicity at production is the dilution of produced fluids to a lower concentration before disposal to sea. However, how confident are we that EOR chemicals do not cause environmental impact to marine life? Due diligence conducted showed that there are no environmental regulations or guidelines in Malaysia for the application of EOR chemicals at an offshore platform. For this reason, our team refers to the strictest of regulation for chemicals' use and discharge for an offshore environment used at the North/Norwegian Sea, adopting all qualification criteria from Harmonized Ocean Chemical Notification Format (HOCNF), of the OSPAR Harmonised Mandatory Control System (HMCS), developed through the OSPAR Decision 2000/2. HOCNF ranks chemical products according to Hazard Quotient (HQ), calculated using the Chemical Hazard and Risk Management (CHARM) model. CHARM is a set of rules to determine the risk and extent of surfactant formulation's movement in the ocean - a vital decision making tool to determine if EOR chemicals are safe for use and overboard discharge. This paper describes the ‘environmental-friendliness’ of a newly developed surfactant formulation which will be applied in a Water-Alternating-Gas (WAG) operation at an offshore field in Malaysia using CHARM. First, a comprehensive review of the components of the formulation was conducted, leading to sound selection and/or synthesis of chemistries that confers good environmental properties i.e. non- or low toxicity, persistency, bioaccumulation, with high biodegradability. Next was to determine the degree of toxicity of the formulation at three trophic levels. Using the lowest acute toxicity value, we apply this value to the CHARM model to calculate the dilution of the formulation 500 m radius from the point of discharge - given the expected adsorption, application concentration, and the volume ratio between squeeze vs. produced water. Whether CHARM is exhaustive to decide if the surfactant formulation can be discharged overboard is still being debated. Many argued that it is the responsibility of the chemical manufacturer or product inventor to select or synthesize chemistries with good ecotoxicity properties in the first place. Product innovation has to be aware on new regulation(s) e.g. the banning on the use of a chemical currently used in manufacturing so that the company develops an alternative ahead of its competitors. In the operator's viewpoint, even if the model indicates that the chemical pose a low hazard, physicochemical parameters of the produced fluids has to be monitored beyond the pilot implementation period.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"457 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76335016","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}
I. Mihaljević, R. Zaki, S. Rana, M. Hegazy, O. Zdraveva
Abrupt and large changes in the earth properties (velocities) can cause conversion of the compressional waves to converted mode energy. Such converted waves could be recorded on the towed streamer seismic data. If they are not identified and removed early they can mislead the interpretation. In this paper, we are showing the successful application of the converted wave attenuation (CWA) workflow on the seismic data from the Mediterranean See, Offshore Egypt. Data is acquired with latest broadband technique and went through several iterations of velocity model building. The presence of the strong converted waves has threatened to undermine velocity model building and interpretation effort. The benefit of presented workflow is that it identifies and models the converted energy pre-stack pre-migration, however the subtraction is done pre-stack post-migration. Post-imaging subtraction gives improved flexibility in signal protection and improvements in the S/N ratio, especially in the areas where the separation of the converted more and compressional energy is small. Presented workflow is universally applicable to any areas where the converted modes occur.
{"title":"Innovative Approach for the Salt-Related Converted-Wave Identification and Attenuation - Offshore Egypt, Mediterranean Sea, Case Study","authors":"I. Mihaljević, R. Zaki, S. Rana, M. Hegazy, O. Zdraveva","doi":"10.2118/192638-ms","DOIUrl":"https://doi.org/10.2118/192638-ms","url":null,"abstract":"\u0000 \u0000 \u0000 Abrupt and large changes in the earth properties (velocities) can cause conversion of the compressional waves to converted mode energy. Such converted waves could be recorded on the towed streamer seismic data. If they are not identified and removed early they can mislead the interpretation. In this paper, we are showing the successful application of the converted wave attenuation (CWA) workflow on the seismic data from the Mediterranean See, Offshore Egypt. Data is acquired with latest broadband technique and went through several iterations of velocity model building. The presence of the strong converted waves has threatened to undermine velocity model building and interpretation effort. The benefit of presented workflow is that it identifies and models the converted energy pre-stack pre-migration, however the subtraction is done pre-stack post-migration. Post-imaging subtraction gives improved flexibility in signal protection and improvements in the S/N ratio, especially in the areas where the separation of the converted more and compressional energy is small. Presented workflow is universally applicable to any areas where the converted modes occur.\u0000","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"2019 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87857648","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}
Salamat Gumarov, S. Benelkadi, Eduardo Bianco, S. Woolf, Chris M. Hardy, Hisataka Ido, Manabu Tanaka, Naohiro Tominaga, K. Yahata, Takeru Okuzawa
Management of drilling wastes presents major challenges during drilling operations in environmentally protected areas. An Abu Dhabi offshore field development project selected cuttings reinjection (CRI) services as an appropriate solution for waste management. Although CRI is a proven technology in the region, fracturing injection always inherits its own containment-related risks. To prevent all possible failures that were experienced earlier in the industry globally, a novel real-time monitoring and analysis of fracturing injections data was introduced. A comprehensive front-end engineering design (FEED) study was performed to evaluate the feasibility of CRI techniques by selecting a suitable injection formation and designing a CRI-dedicated well, surface facilities, slurry testing, and appropriate operations execution plan. The CRI well was drilled and completed to accommodate waste volumes. An assurance program based on industry best practices was used to support zero solids settling, fracture, or perforation plugging. To achieve on-time intervention, the first real-time CRI data transfer through a satellite-based network to a support center staffed by global experts in Abu Dhabi was deployed to analyze fracture injection and shut-in pressure responses for early identification of possible risks and to map the fracture waste domain. The project has been operated successfully since its inception with more than 300,000 bbl of drilled cuttings and drilling waste fluids injected since July 2016. No injectivity issues were experienced during drilling waste fluids injection. Several on-time interventions had been made to prevent well plugging and to maintain surface injection pressures within normal ranges. Real-time data streaming has made a step-change improvement in the data delivery process, monitoring, and fracture pressure analysis. It creates a direct link between the wellsite and worldwide multidisciplinary technical expertise centralized in Abu Dhabi and provides visualization capability at any time and to any where to all personnel involved in the project. This step change in monitoring CRI operations provides an acquisition-to-answer" integrated solution, mitigates the injection risks, and enhances the intrinsic value of CRI services. The paper shares the experience of implementing the novel real-time CRI subsurface injection assurance program dedicated for cuttings reinjection operations. Real-time support from multidisciplinary experts provides live injection monitoring and fracture waste domain mapping for highly complex and risk-prone subsurface injection environments with stringent regulations
{"title":"First Implementation of Real-Time Subsurface Monitoring for Cuttings Reinjection Offshore Abu Dhabi","authors":"Salamat Gumarov, S. Benelkadi, Eduardo Bianco, S. Woolf, Chris M. Hardy, Hisataka Ido, Manabu Tanaka, Naohiro Tominaga, K. Yahata, Takeru Okuzawa","doi":"10.2118/192884-ms","DOIUrl":"https://doi.org/10.2118/192884-ms","url":null,"abstract":"\u0000 Management of drilling wastes presents major challenges during drilling operations in environmentally protected areas. An Abu Dhabi offshore field development project selected cuttings reinjection (CRI) services as an appropriate solution for waste management.\u0000 Although CRI is a proven technology in the region, fracturing injection always inherits its own containment-related risks. To prevent all possible failures that were experienced earlier in the industry globally, a novel real-time monitoring and analysis of fracturing injections data was introduced.\u0000 A comprehensive front-end engineering design (FEED) study was performed to evaluate the feasibility of CRI techniques by selecting a suitable injection formation and designing a CRI-dedicated well, surface facilities, slurry testing, and appropriate operations execution plan.\u0000 The CRI well was drilled and completed to accommodate waste volumes. An assurance program based on industry best practices was used to support zero solids settling, fracture, or perforation plugging.\u0000 To achieve on-time intervention, the first real-time CRI data transfer through a satellite-based network to a support center staffed by global experts in Abu Dhabi was deployed to analyze fracture injection and shut-in pressure responses for early identification of possible risks and to map the fracture waste domain.\u0000 The project has been operated successfully since its inception with more than 300,000 bbl of drilled cuttings and drilling waste fluids injected since July 2016. No injectivity issues were experienced during drilling waste fluids injection. Several on-time interventions had been made to prevent well plugging and to maintain surface injection pressures within normal ranges.\u0000 Real-time data streaming has made a step-change improvement in the data delivery process, monitoring, and fracture pressure analysis. It creates a direct link between the wellsite and worldwide multidisciplinary technical expertise centralized in Abu Dhabi and provides visualization capability at any time and to any where to all personnel involved in the project.\u0000 This step change in monitoring CRI operations provides an acquisition-to-answer\" integrated solution, mitigates the injection risks, and enhances the intrinsic value of CRI services.\u0000 The paper shares the experience of implementing the novel real-time CRI subsurface injection assurance program dedicated for cuttings reinjection operations. Real-time support from multidisciplinary experts provides live injection monitoring and fracture waste domain mapping for highly complex and risk-prone subsurface injection environments with stringent regulations","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"1 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86901575","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}
C. Temizel, A. Abdullayev, Rachit Kedia, S. Chhabra
One method of reducing the recognized threat of global warming is using continued sequestration of anthropogenic "greenhouse gases," such as carbon dioxide (CO2). Sedimentary basins are present globally and, because of the omnipresent nature of deep, regional-scale aquifers within them, they can be considered as potential sites for disposal and sequestration of CO2. Successful implementation requires identifying and considering fundamental concepts to help ensure that CO2 is stored in the aquifers effectively. The ideal scenario involves migrating CO2 from injection wells to remote storage sites using the aquifer, helping ensure its isolation from the atmosphere for a considerable length of time. In addition to the scientific and technical aspects of sequestration research, the practicality of the concept should be considered, including evaluating the maximum possible volume of CO2 that can be stored at global and regional levels as well as the safety and economic feasibility of the process. This study discusses examples to help provide an in-depth, practical understanding of this concept. The study combines a full-physics commercial simulator with an effective uncertainty and optimization tool. The sequestration phenomenon is then modeled to investigate the significance and effect of the essential parameters on well performance while also considering thermal and geochemical effects. The process assesses the injection of CO2 containing tracers for 25 years, followed by shutting in the injectors and modeling the status of CO2 for the next 225 years. While CO2 is injected into an aquifer, the molecular diffusion of CO2 in water is modeled. The modeling of the thermal effects attributable to the injection of CO2 is important because the chemical equilibrium constants have a functional thermal dependency. For reservoir management, the evaluation and effective management of uncertainties are as important as managing the well-level parameters. For this study, essential reservoir and well parameters are identified, and sensitivity and optimization processes are performed on them; the tornado charts in this paper illustrate the significance and effect of each parameter. Thermal and geochemical effects are shown to play vital roles in the sequestration process. This study outlines the significance of essential parameters associated with the overall success of the CO2 sequestration in aquifers using in-depth uncertainty and optimization analysis, and it considers the influence of thermal and geochemical effects.
{"title":"CO2 Sequestration Optimization in Aquifers While Considering Thermal and Geochemical Effects","authors":"C. Temizel, A. Abdullayev, Rachit Kedia, S. Chhabra","doi":"10.2118/192683-MS","DOIUrl":"https://doi.org/10.2118/192683-MS","url":null,"abstract":"\u0000 One method of reducing the recognized threat of global warming is using continued sequestration of anthropogenic \"greenhouse gases,\" such as carbon dioxide (CO2). Sedimentary basins are present globally and, because of the omnipresent nature of deep, regional-scale aquifers within them, they can be considered as potential sites for disposal and sequestration of CO2. Successful implementation requires identifying and considering fundamental concepts to help ensure that CO2 is stored in the aquifers effectively. The ideal scenario involves migrating CO2 from injection wells to remote storage sites using the aquifer, helping ensure its isolation from the atmosphere for a considerable length of time. In addition to the scientific and technical aspects of sequestration research, the practicality of the concept should be considered, including evaluating the maximum possible volume of CO2 that can be stored at global and regional levels as well as the safety and economic feasibility of the process. This study discusses examples to help provide an in-depth, practical understanding of this concept.\u0000 The study combines a full-physics commercial simulator with an effective uncertainty and optimization tool. The sequestration phenomenon is then modeled to investigate the significance and effect of the essential parameters on well performance while also considering thermal and geochemical effects. The process assesses the injection of CO2 containing tracers for 25 years, followed by shutting in the injectors and modeling the status of CO2 for the next 225 years. While CO2 is injected into an aquifer, the molecular diffusion of CO2 in water is modeled. The modeling of the thermal effects attributable to the injection of CO2 is important because the chemical equilibrium constants have a functional thermal dependency.\u0000 For reservoir management, the evaluation and effective management of uncertainties are as important as managing the well-level parameters. For this study, essential reservoir and well parameters are identified, and sensitivity and optimization processes are performed on them; the tornado charts in this paper illustrate the significance and effect of each parameter. Thermal and geochemical effects are shown to play vital roles in the sequestration process.\u0000 This study outlines the significance of essential parameters associated with the overall success of the CO2 sequestration in aquifers using in-depth uncertainty and optimization analysis, and it considers the influence of thermal and geochemical effects.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"113 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86985356","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
A. Ali, Sangseok Park, Muhammad Mukhtar, K. Ghorayeb, Mohamad Alkhatib, Aditiya Ojha, Abdur Rahman Shah, J. Ortiz
Early assessment of enhanced oil recovery (EOR) potential in fields that are at early development stages is becoming more common in the oil industry, ensuring that investment decisions are consistent with the EOR deployment once the field reaches maturity. Well, facilities and monitoring design maybe influenced to accommodate the EOR implementation, thus reducing Capex and mitigating project exposure. Challenges arise, as expected, due to the limited information, particularly when the field has not yet been under production and dynamic information of connectivity, compartmentalization and reservoir extend is scarce. This paper describes the screening analysis performed on an onshore marginal green field in the UAE with four drilled wells and no production history with water injection considered on the approved development plan. The comprehensive screening workflow resulted on a narrow list of potential applicable EOR methods and their corresponding benefits allowing the operator to tailor development activities for early EOR de-risking and accelerated field deployment. A multi-dimensional approach was adopted using a combination of numerical, analytical methods and past EOR experience, to shortlist and rank the most attractive EOR development options, robustness of the selection (and ranking) was tested under the key reservoir uncertainties. WAG was identified as one of the better suited EOR processes (complemented the planned waterflood) along with miscible CO2 injection (with possible WAG applications).
{"title":"Robust EOR Screening Workflow for a Carbonate Green Field: A Case Study","authors":"A. Ali, Sangseok Park, Muhammad Mukhtar, K. Ghorayeb, Mohamad Alkhatib, Aditiya Ojha, Abdur Rahman Shah, J. Ortiz","doi":"10.2118/192700-MS","DOIUrl":"https://doi.org/10.2118/192700-MS","url":null,"abstract":"\u0000 Early assessment of enhanced oil recovery (EOR) potential in fields that are at early development stages is becoming more common in the oil industry, ensuring that investment decisions are consistent with the EOR deployment once the field reaches maturity. Well, facilities and monitoring design maybe influenced to accommodate the EOR implementation, thus reducing Capex and mitigating project exposure. Challenges arise, as expected, due to the limited information, particularly when the field has not yet been under production and dynamic information of connectivity, compartmentalization and reservoir extend is scarce.\u0000 This paper describes the screening analysis performed on an onshore marginal green field in the UAE with four drilled wells and no production history with water injection considered on the approved development plan. The comprehensive screening workflow resulted on a narrow list of potential applicable EOR methods and their corresponding benefits allowing the operator to tailor development activities for early EOR de-risking and accelerated field deployment. A multi-dimensional approach was adopted using a combination of numerical, analytical methods and past EOR experience, to shortlist and rank the most attractive EOR development options, robustness of the selection (and ranking) was tested under the key reservoir uncertainties.\u0000 WAG was identified as one of the better suited EOR processes (complemented the planned waterflood) along with miscible CO2 injection (with possible WAG applications).","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"82 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87359550","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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