A. Kashlev, A. Fedotov, A. Philippov, E. Sayapov, A. Moiseyenkov
Global depression in the oil market has recently been the main driver in forcing oil companies to discover more efficient solutions to produce hydrocarbons, as well as to optimize existing strategies and practices, whereas multilateral and branched well completion technologies act as a tool for improving performance of both new and existing well stocks. These services have been among the premium products offered by oilfield service majors. High cost of this service derives from a limited number of players that are capable of offering and executing such high technology operations, as well as from insufficient field exposure making each implementation very unique and therefore expensive. The advantages of multilateral wells are well-known in the industry. The most obvious ones are: CAPEX savings on upper completion.Step increase of the drainage area.Wells infill drilling without expanding surface infrastructure.
{"title":"Smart and Innovative Approach that Makes Multilateral Well Construction Efficient and Economical for Worldwide Application","authors":"A. Kashlev, A. Fedotov, A. Philippov, E. Sayapov, A. Moiseyenkov","doi":"10.2118/197253-ms","DOIUrl":"https://doi.org/10.2118/197253-ms","url":null,"abstract":"\u0000 Global depression in the oil market has recently been the main driver in forcing oil companies to discover more efficient solutions to produce hydrocarbons, as well as to optimize existing strategies and practices, whereas multilateral and branched well completion technologies act as a tool for improving performance of both new and existing well stocks.\u0000 These services have been among the premium products offered by oilfield service majors. High cost of this service derives from a limited number of players that are capable of offering and executing such high technology operations, as well as from insufficient field exposure making each implementation very unique and therefore expensive.\u0000 The advantages of multilateral wells are well-known in the industry. The most obvious ones are: CAPEX savings on upper completion.Step increase of the drainage area.Wells infill drilling without expanding surface infrastructure.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"61 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90650276","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. Gutierrez, M. Saleh, Ayoub Hadj-moussa, M. A. Alzaabi, I. Abdelkarim, Mario R. Oviedo Vargas, Olla Kadoura, Mohamed Ahmed Osman, Bilal Iftikhar Choudhry, Javier Ernesto Torres Premoli
In a specific reservoir of an offshore field Abu Dhabi, several layers of the reservoir are producing subject to pressure depletion while other layers are partially or over pressurized due to water injection. Drilling through multi-layered reservoirs involves several challenges: faults and fractures, differentially stuck pipe and even total loss/kick scenarios due to pressure difference between the different layers. For reentry wells isolating the producing from injection layers is not possible due to the existing well schematic restrictions, completion requirements and target hole drainage size and location. MPD was proposed to utilize a mud weight that minimizes the differential pressure between the producing and injecting layers within reservoir which mitigates the drilling problems related to high differential pressure. The game plan was to start drilling the depleted zone with the lowest possible mud weight and to enter the injecting zone (higher pressure) with this mud weight to calculate the exact pressure of the formation using the early kick detection and automatic control features of the fully automated MPD system, in this way reducing the amount of overbalance in the depleted layer if feasible. Two wells were drilling using this method successfully. On both wells, a lower than conventional mud weight drilling fluids was used and the MPD system tested and verified the pore pressure of each of the reservoir layers. The calculated pore pressures were less than the wells prognosis. Swaying from the conventional mud weight consideration and the verification of pore pressure did minimize the differential pressure across the two layers which eventually eliminated the chances of drilling fluids losses and drill pipe differential stuck. The fully automated MPD system dealt safely with all the influxes during the pore pressure verifications tests. The new approach succeeded in solving the high differential pressure problem in the reservoir as drilling progressed shoe-to-shoe without interruption. The lower mud weight used had extra benefits in areas that historically required none-damaging weighting agent, this requirement was avoided by eliminating the need for this agent, FPWD was recorded across depleted reservoirs without pipe stuck events. Moreover, it was obvious the rate of penetration was higher on these two wells than offset wells in the same field when conventional mud was used. For the first time in the UAE a closed-loop fully automated MPD system was utilized to lower the mud weight used when drilling across the reservoir, first time dynamic pore pressure tests were utilized to ascertain the wells prognosis and the first time FPWD was successfully recorded under substantially high differential pressure. In conclusion, the MPD was proven to be the right solution to overcome the uncertainty in pressure resulted from pressure maintenance program and reservoir depletion.
{"title":"Drilling Through Multi-Layered Reservoirs Using MPD to Minimize Differential Pressure Effect by Predicting and Optimizing Required MW","authors":"F. Gutierrez, M. Saleh, Ayoub Hadj-moussa, M. A. Alzaabi, I. Abdelkarim, Mario R. Oviedo Vargas, Olla Kadoura, Mohamed Ahmed Osman, Bilal Iftikhar Choudhry, Javier Ernesto Torres Premoli","doi":"10.2118/197755-ms","DOIUrl":"https://doi.org/10.2118/197755-ms","url":null,"abstract":"\u0000 In a specific reservoir of an offshore field Abu Dhabi, several layers of the reservoir are producing subject to pressure depletion while other layers are partially or over pressurized due to water injection. Drilling through multi-layered reservoirs involves several challenges: faults and fractures, differentially stuck pipe and even total loss/kick scenarios due to pressure difference between the different layers. For reentry wells isolating the producing from injection layers is not possible due to the existing well schematic restrictions, completion requirements and target hole drainage size and location.\u0000 MPD was proposed to utilize a mud weight that minimizes the differential pressure between the producing and injecting layers within reservoir which mitigates the drilling problems related to high differential pressure. The game plan was to start drilling the depleted zone with the lowest possible mud weight and to enter the injecting zone (higher pressure) with this mud weight to calculate the exact pressure of the formation using the early kick detection and automatic control features of the fully automated MPD system, in this way reducing the amount of overbalance in the depleted layer if feasible.\u0000 Two wells were drilling using this method successfully. On both wells, a lower than conventional mud weight drilling fluids was used and the MPD system tested and verified the pore pressure of each of the reservoir layers. The calculated pore pressures were less than the wells prognosis. Swaying from the conventional mud weight consideration and the verification of pore pressure did minimize the differential pressure across the two layers which eventually eliminated the chances of drilling fluids losses and drill pipe differential stuck. The fully automated MPD system dealt safely with all the influxes during the pore pressure verifications tests. The new approach succeeded in solving the high differential pressure problem in the reservoir as drilling progressed shoe-to-shoe without interruption. The lower mud weight used had extra benefits in areas that historically required none-damaging weighting agent, this requirement was avoided by eliminating the need for this agent, FPWD was recorded across depleted reservoirs without pipe stuck events. Moreover, it was obvious the rate of penetration was higher on these two wells than offset wells in the same field when conventional mud was used.\u0000 For the first time in the UAE a closed-loop fully automated MPD system was utilized to lower the mud weight used when drilling across the reservoir, first time dynamic pore pressure tests were utilized to ascertain the wells prognosis and the first time FPWD was successfully recorded under substantially high differential pressure. In conclusion, the MPD was proven to be the right solution to overcome the uncertainty in pressure resulted from pressure maintenance program and reservoir depletion.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"118 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"88495356","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}
U. Devarajan, Jagadesh Chandrasekaran, Raju Paul, F. Kamal, Oussama Takieddine
The Design, Installation, commissioning and handover of Custody metering system is very very critical for any project completion. This paper addresses major challenges and the corresponding mitigation methodologies in the design of a custody metering system in an unstabilized crude application in recent Buhasser FFD project. Custody meter is provided for measuring the Oil production from Bu Haseer Production Separator in Zakum plant at Das Island. The Custody meter is fiscal type and designed as a packaged unit. Custody meter package consist of one working, one standby arrangement and one common pipe proving system. The Metering Package includes the following main equipment and instruments: Coriolis flow meters.Pressure and Temperature transmitters.Proving system with double block and bleed valves.Automatic Sampling systemFlow computing systemInlet/Outlet Valves (MOVs) The Bu Haseer Oil at the outlet of Custody meter is routed to the existing Zakum Inlet oil manifold which is feeding to all existing Separation trains in the Zakum plant.
{"title":"Challenges in Custody Metering System in Unstabilized Crude","authors":"U. Devarajan, Jagadesh Chandrasekaran, Raju Paul, F. Kamal, Oussama Takieddine","doi":"10.2118/197559-ms","DOIUrl":"https://doi.org/10.2118/197559-ms","url":null,"abstract":"\u0000 The Design, Installation, commissioning and handover of Custody metering system is very very critical for any project completion. This paper addresses major challenges and the corresponding mitigation methodologies in the design of a custody metering system in an unstabilized crude application in recent Buhasser FFD project.\u0000 Custody meter is provided for measuring the Oil production from Bu Haseer Production Separator in Zakum plant at Das Island. The Custody meter is fiscal type and designed as a packaged unit. Custody meter package consist of one working, one standby arrangement and one common pipe proving system. The Metering Package includes the following main equipment and instruments: Coriolis flow meters.Pressure and Temperature transmitters.Proving system with double block and bleed valves.Automatic Sampling systemFlow computing systemInlet/Outlet Valves (MOVs)\u0000 The Bu Haseer Oil at the outlet of Custody meter is routed to the existing Zakum Inlet oil manifold which is feeding to all existing Separation trains in the Zakum plant.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"81051180","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}
Xing Zhao, Hehua Wang, Lize Lu, Liu Zhibin, Enjie He
For prediction of the post production of acid fracturing, a numerical method has been introduced in this paper. This prediction approach is developed by the dynamic differential modeling method for forecasting single well acid fracturing performance. In this study, the average production during 30 days and fracture geometry after acid fracturing were determined as predicted indices. Fifteen parameters were considered as influencing factors consisted of geological, reservoir and treatment parameters. The field data of predicted indices and influencing parameters were collected from the data of 7 acid-fractured wells in the XB oil field. The historical data was input into the dynamic differential model to establish and discretize the relation functions. Three target well were chosen and their corresponding influencing factors were used to calculate the predicted indices. The results showed that for the target wells, the modeling predicted indices were fairly close to the real numbers. This model is practical for the engineer in the field since the input parameter acquisition is accessible from the common oil field data. It could help the engineers to optimize the acid fracturing treatment design by correlating the scale of the treatment.
{"title":"Performance Prediction and Optimization of Acid Fracturing Based on the Dynamic Differential Modeling Method","authors":"Xing Zhao, Hehua Wang, Lize Lu, Liu Zhibin, Enjie He","doi":"10.2118/197943-ms","DOIUrl":"https://doi.org/10.2118/197943-ms","url":null,"abstract":"\u0000 For prediction of the post production of acid fracturing, a numerical method has been introduced in this paper. This prediction approach is developed by the dynamic differential modeling method for forecasting single well acid fracturing performance. In this study, the average production during 30 days and fracture geometry after acid fracturing were determined as predicted indices. Fifteen parameters were considered as influencing factors consisted of geological, reservoir and treatment parameters. The field data of predicted indices and influencing parameters were collected from the data of 7 acid-fractured wells in the XB oil field. The historical data was input into the dynamic differential model to establish and discretize the relation functions. Three target well were chosen and their corresponding influencing factors were used to calculate the predicted indices. The results showed that for the target wells, the modeling predicted indices were fairly close to the real numbers. This model is practical for the engineer in the field since the input parameter acquisition is accessible from the common oil field data. It could help the engineers to optimize the acid fracturing treatment design by correlating the scale of the treatment.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"31 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84549814","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}
Offset wells in this region for the past 20 years were used as water disposal wells, having 40,000 bpd water production. Past decade observed remarkable decline in production leading to the development of the current well as a replacement while abandoning the previous well. The well was ranked as medium critical considered from its long water disposal period as no integrity test were performed due to the well location. The lithology of anhydrite alternation with limestone, dolomite and thin shale layers caused a risk of losses and differential sticking. In addition, this was a H2S bearing (100 - 119ppm) salt-water flow formation. With a rotating control head in place with the flow line valve closed providing a closed loop system, the return is dumped to the sea through the extended diverter lines, ensuring that the H2S emissions are diverted away from the rig floor and from the manned complexes. Total losses and sour water flow made closed loop flow drilling an engineering solution for its ability to ensure no H2S migration to the rig floor and continuity of the drilling operation with returns diverted away from the rig at all times. The introduction of side entry flow line on the rotating control device (RCD) allowed utilization of an additional fill up line planned to bullhead back to the formation preventing excessive gas migration. Extensive planning of rig interface with rotating control head with side inlet connection from the standpipe manifold to manage time and space constraints in addition to losses management providing well continuity. The well drilled successfully with a rotating control device- RCD at surface and returns diverted safely. The closed system with rotating control device - RCD and a well head pressure monitoring gauge provided an additional security of analyzing well conditions, though risk of having gas influx was initially identified as a medium hazard being a top hole section with a higher chances of losses while drilling. As circulation and conditioning was done traces of gas and H2S were observed with an increase in pressure observed at the RCD. Bullheading from the side inlet of the RCD from standpipe was utilized to balance the well eliminating the risk of high exposure of H2S gas at surface. Having the only pressure monitoring system in place with the RCD the overhead pressure could be identified to raise the mud weight and to balance the well. This operation was successful and resulted in zero gas at surface with casing and cementing operations on the well conducted safely without any quality, health or safety issues. Understanding the risk of less information about the formation led to the approach of utilizing a low pressure rotating head system to drill safely into a H2S risk zone. This paper identifies how a previously used system, could have an innovated approach to drill safely in a total loss and H2S prone formations.
{"title":"HSE Closed Loop Drilling for Well Integrity","authors":"Jobin Abraham, M. Saleh, Ayoub Hadj-moussa","doi":"10.2118/197467-ms","DOIUrl":"https://doi.org/10.2118/197467-ms","url":null,"abstract":"\u0000 Offset wells in this region for the past 20 years were used as water disposal wells, having 40,000 bpd water production. Past decade observed remarkable decline in production leading to the development of the current well as a replacement while abandoning the previous well. The well was ranked as medium critical considered from its long water disposal period as no integrity test were performed due to the well location. The lithology of anhydrite alternation with limestone, dolomite and thin shale layers caused a risk of losses and differential sticking. In addition, this was a H2S bearing (100 - 119ppm) salt-water flow formation.\u0000 With a rotating control head in place with the flow line valve closed providing a closed loop system, the return is dumped to the sea through the extended diverter lines, ensuring that the H2S emissions are diverted away from the rig floor and from the manned complexes.\u0000 Total losses and sour water flow made closed loop flow drilling an engineering solution for its ability to ensure no H2S migration to the rig floor and continuity of the drilling operation with returns diverted away from the rig at all times. The introduction of side entry flow line on the rotating control device (RCD) allowed utilization of an additional fill up line planned to bullhead back to the formation preventing excessive gas migration.\u0000 Extensive planning of rig interface with rotating control head with side inlet connection from the standpipe manifold to manage time and space constraints in addition to losses management providing well continuity.\u0000 The well drilled successfully with a rotating control device- RCD at surface and returns diverted safely. The closed system with rotating control device - RCD and a well head pressure monitoring gauge provided an additional security of analyzing well conditions, though risk of having gas influx was initially identified as a medium hazard being a top hole section with a higher chances of losses while drilling.\u0000 As circulation and conditioning was done traces of gas and H2S were observed with an increase in pressure observed at the RCD. Bullheading from the side inlet of the RCD from standpipe was utilized to balance the well eliminating the risk of high exposure of H2S gas at surface. Having the only pressure monitoring system in place with the RCD the overhead pressure could be identified to raise the mud weight and to balance the well. This operation was successful and resulted in zero gas at surface with casing and cementing operations on the well conducted safely without any quality, health or safety issues.\u0000 Understanding the risk of less information about the formation led to the approach of utilizing a low pressure rotating head system to drill safely into a H2S risk zone. This paper identifies how a previously used system, could have an innovated approach to drill safely in a total loss and H2S prone formations.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"35 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83216211","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}
Sriyanta Hadi, M. A. A. Wahab, Budi Mawardi Nasron, Wira Abadi Sharkawi, Nazri Abdul Latiff
Relevant to maximizing oil recovery, water injection is implemented for reservoir pressure maintenance and to maximize oil sweeping. The water injection involves both surface and subsurface matters. Since the objective is reservoir pressure maintenance and oil sweeping efficiency improvement, the subsurface domain includes reservoir engineering, geology and geophysics as well as the production technology. For surface operations, the water injection operation includes water injection source, water plant operations and water injection infrastructure. Water injection bottle neck and water quality issue may occur and damage the water injection efficiency. An idea of molecule to molecule (M2M) water injection performance review is raised to conduct a comprehensive and collaborative water injection review that involving many and outreach parties such as reservoir engineers, geologists, geophysicists, operation engineers, production chemists, production technologists, maintenance engineers, production planners and process engineers. The opportunity to include technical providers, partner representatives and host government representatives is taken in order to allow an effective discussion and quicken the maturing of relevant solution proposals. Comprehensive end to end review from the point of water source up to the point of producer is done to identify problem at each point, threats and improvement opportunities at every single node within the whole chain. With the M2M, water injection performance review has effectively provided an effective collaborative working environment as well as a learning avenue for young professionals that are involved in water injection matters. Many action items are resulted from the exercise and they are having high impact including safeguarding potential cost of USD 10 million per year for the water injection plant and infrastructure operations. In the short run, no disturbances for oil production and in the long run, the oil recovery can be maximized. Due to some limitation, this paper discusses only the surface water injection operations.
{"title":"Molecule to Molecule M2M Water Injection Performance Review to Achieve Water Injection Excellence in PETRONAS – Part 1 Surface Operations","authors":"Sriyanta Hadi, M. A. A. Wahab, Budi Mawardi Nasron, Wira Abadi Sharkawi, Nazri Abdul Latiff","doi":"10.2118/197363-ms","DOIUrl":"https://doi.org/10.2118/197363-ms","url":null,"abstract":"\u0000 Relevant to maximizing oil recovery, water injection is implemented for reservoir pressure maintenance and to maximize oil sweeping. The water injection involves both surface and subsurface matters. Since the objective is reservoir pressure maintenance and oil sweeping efficiency improvement, the subsurface domain includes reservoir engineering, geology and geophysics as well as the production technology. For surface operations, the water injection operation includes water injection source, water plant operations and water injection infrastructure. Water injection bottle neck and water quality issue may occur and damage the water injection efficiency. An idea of molecule to molecule (M2M) water injection performance review is raised to conduct a comprehensive and collaborative water injection review that involving many and outreach parties such as reservoir engineers, geologists, geophysicists, operation engineers, production chemists, production technologists, maintenance engineers, production planners and process engineers. The opportunity to include technical providers, partner representatives and host government representatives is taken in order to allow an effective discussion and quicken the maturing of relevant solution proposals. Comprehensive end to end review from the point of water source up to the point of producer is done to identify problem at each point, threats and improvement opportunities at every single node within the whole chain. With the M2M, water injection performance review has effectively provided an effective collaborative working environment as well as a learning avenue for young professionals that are involved in water injection matters. Many action items are resulted from the exercise and they are having high impact including safeguarding potential cost of USD 10 million per year for the water injection plant and infrastructure operations. In the short run, no disturbances for oil production and in the long run, the oil recovery can be maximized. Due to some limitation, this paper discusses only the surface water injection operations.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"54 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82282516","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. A. Awadhi, S. Narayana, Alya Al Ahmad, S. Qamar, Shahid Rafiq
The rapid induction of Fiber Reinforced Plastics (FRP) into process industry due to high corrosion resistance and cost effectiveness made End Users to overlook FRP's specific design, fabrication and quality control aspects. This also affected various Utility and firewater networks in ADNOC Gas Processing plants. It is addressed by enhancing Vendor pre-qualification, relevant specifications and construction procedures. This paper presents measures adopted to ensure reliable design, supply and installation of FRP piping systems. FRP piping systems have unique design/construction requirements that was not followed in totality in AGP past installations. Also, international standards do not offer adequate guidance on design, resins selection, fabrication methods and joint systems. Vendors were trusted upon for complete design. A campaign is initiated to engage FRP pipe manufacturer having binding single point responsibility from beginning of project for particular FRP system design to ensure desired performance of FRP piping system with extended warranty. Measures have been taken to improve quality material supply through enhanced vendor pre-qualification, ADNOC Gas Processing specifications and CONTRACTORS pre-qualification having certified site crew. Studies revealed that material quality, velocity/surge pressure were the main contributing factors for failures which were not adequately addressed in design of FRP piping systems. Gaps noticed in previous projects were use of inadequate Codes, Composite's mechanical properties, design approach, inadequate joint preparation and QA/QC in construction phase. During manufacturing using wrong resin can be a cause for premature failure. Absence of certified personnel for project execution and Non-compliance of manufacturer's instructions were also key lapses noted in construction phase. The gaps in design process, necessitated improvement and consolidation of ADNOC Gas Processing existing design specifications/criteria and analysis requirements which now mandate that the required hydraulic / surge / static analysis shall be carried out by pre-qualified FRP manufacturer. Material property issues were addressed by clearly specifying the material composition & properties requirements and procedural requirements for storage are incorporated into the manufacturing process, along with mandating minimum prior experience for the manufacturers for material supply and design. Certification of contractor's personnel and presence of FRP manufacturer's representative at site during construction and pre-commissioning has been emphasized as mandatory requirement. In addition Specialist 3rd party inspection/supervision must be deployed to ensure quality control during every step of construction and commissioning Design specifications, procedures, manufacturing process, QA/QC and installation methods for FRP piping systems are available, but lacked activity interface between consultant, vendor and contractor. ADNOC Gas
{"title":"Best Practices in Integrity Management of Safety Critical Systems","authors":"I. A. Awadhi, S. Narayana, Alya Al Ahmad, S. Qamar, Shahid Rafiq","doi":"10.2118/197175-ms","DOIUrl":"https://doi.org/10.2118/197175-ms","url":null,"abstract":"\u0000 The rapid induction of Fiber Reinforced Plastics (FRP) into process industry due to high corrosion resistance and cost effectiveness made End Users to overlook FRP's specific design, fabrication and quality control aspects. This also affected various Utility and firewater networks in ADNOC Gas Processing plants. It is addressed by enhancing Vendor pre-qualification, relevant specifications and construction procedures. This paper presents measures adopted to ensure reliable design, supply and installation of FRP piping systems.\u0000 FRP piping systems have unique design/construction requirements that was not followed in totality in AGP past installations. Also, international standards do not offer adequate guidance on design, resins selection, fabrication methods and joint systems. Vendors were trusted upon for complete design. A campaign is initiated to engage FRP pipe manufacturer having binding single point responsibility from beginning of project for particular FRP system design to ensure desired performance of FRP piping system with extended warranty. Measures have been taken to improve quality material supply through enhanced vendor pre-qualification, ADNOC Gas Processing specifications and CONTRACTORS pre-qualification having certified site crew.\u0000 Studies revealed that material quality, velocity/surge pressure were the main contributing factors for failures which were not adequately addressed in design of FRP piping systems. Gaps noticed in previous projects were use of inadequate Codes, Composite's mechanical properties, design approach, inadequate joint preparation and QA/QC in construction phase. During manufacturing using wrong resin can be a cause for premature failure. Absence of certified personnel for project execution and\u0000 Non-compliance of manufacturer's instructions were also key lapses noted in construction phase. The gaps in design process, necessitated improvement and consolidation of ADNOC Gas Processing existing design specifications/criteria and analysis requirements which now mandate that the required hydraulic / surge / static analysis shall be carried out by pre-qualified FRP manufacturer. Material property issues were addressed by clearly specifying the material composition & properties requirements and procedural requirements for storage are incorporated into the manufacturing process, along with mandating minimum prior experience for the manufacturers for material supply and design. Certification of contractor's personnel and presence of FRP manufacturer's representative at site during construction and pre-commissioning has been emphasized as mandatory requirement. In addition Specialist 3rd party inspection/supervision must be deployed to ensure quality control during every step of construction and commissioning\u0000 Design specifications, procedures, manufacturing process, QA/QC and installation methods for FRP piping systems are available, but lacked activity interface between consultant, vendor and contractor. ADNOC Gas","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"59 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"76480193","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}
Reservoir simulation results currently provide the basis for important reservoir engineering decisions; grid complexity and non-linearity of these models demand high computational time and memory. The physics-based simulation process must be repeated to increase model prediction accuracy or to perform history matching; consequently, the simulation process is often time-consuming. This paper describes a new methodology based on a deep neural network (DNN) technique, the graph convolutional neural network (G-CNN). G-CNN increases the modeling prediction speed and efficiency by compressing the computational time and memory usage of the reservoir simulation. A G-CNN model was used to perform the reservoir simulations described. This new methodology combines physics-based and data-driven models in reservoir simulation. The workflow generates training datasets, enabling intelligent sampling of the reservoir production data in the G-CNN training process. Bottomhole pressure constraints were set for all simulations. The production data generated by the reservoir model, with the mesh connectivity information, is used to generate the G-CNN model. This approach can be viewed as hybrid data-driven, retaining the underlying physics of the reservoir simulator. The resulting G-CNN model can perform reservoir simulations for any computational grid and production time horizon. The method uses convolutional neural network and mesh connections in a fully differentiable scheme to compress the simulation state size and learns the reservoir dynamics on this compressed form. G-CNN analysis was performed on an Eagle Ford-type reservoir model. The transmissibility, pore volume, pressure, and saturation at an initial time state were used as input features to predict final pressure and saturations. Prediction accuracy of 95% was obtained by hyperparameter tuning off the G-CNN architecture. By compressing the simulation state size and learning the time-dependent reservoir dynamics on this compressed representation, reservoir simulations can be emulated by a graph neural network which uses significantly less computation and memory. The G-CNN model can be used on any computational grid because it preserves the structure of the physics. The G-CNN model is trained by mapping an initial time state to a future prediction time state; consequently, the model can be used for generalizing predictions in any grid sizes and time steps while maintaining accuracy. The result is a computationally and memory efficient neural network that can be iterated and queried to reproduce a reservoir simulation. This novel methodology combines field-scale physics-based reservoir modeling and DNN for reservoir simulations. The new reservoir simulation workflow, based on the G-CNN model, maps the time state predictions in a resampled grid, reducing computational time and memory. The new methodology presents a general method for compressing reservoir simulations, assisting in fast and accurate prod
{"title":"Compressing Time-Dependent Reservoir Simulations Using Graph-Convolutional Neural Network G-CNN","authors":"S. Madasu, S. Siddiqui, Keshava P. Rangarajan","doi":"10.2118/197444-ms","DOIUrl":"https://doi.org/10.2118/197444-ms","url":null,"abstract":"\u0000 Reservoir simulation results currently provide the basis for important reservoir engineering decisions; grid complexity and non-linearity of these models demand high computational time and memory. The physics-based simulation process must be repeated to increase model prediction accuracy or to perform history matching; consequently, the simulation process is often time-consuming. This paper describes a new methodology based on a deep neural network (DNN) technique, the graph convolutional neural network (G-CNN). G-CNN increases the modeling prediction speed and efficiency by compressing the computational time and memory usage of the reservoir simulation. A G-CNN model was used to perform the reservoir simulations described.\u0000 This new methodology combines physics-based and data-driven models in reservoir simulation. The workflow generates training datasets, enabling intelligent sampling of the reservoir production data in the G-CNN training process. Bottomhole pressure constraints were set for all simulations. The production data generated by the reservoir model, with the mesh connectivity information, is used to generate the G-CNN model. This approach can be viewed as hybrid data-driven, retaining the underlying physics of the reservoir simulator. The resulting G-CNN model can perform reservoir simulations for any computational grid and production time horizon. The method uses convolutional neural network and mesh connections in a fully differentiable scheme to compress the simulation state size and learns the reservoir dynamics on this compressed form.\u0000 G-CNN analysis was performed on an Eagle Ford-type reservoir model. The transmissibility, pore volume, pressure, and saturation at an initial time state were used as input features to predict final pressure and saturations. Prediction accuracy of 95% was obtained by hyperparameter tuning off the G-CNN architecture. By compressing the simulation state size and learning the time-dependent reservoir dynamics on this compressed representation, reservoir simulations can be emulated by a graph neural network which uses significantly less computation and memory. The G-CNN model can be used on any computational grid because it preserves the structure of the physics. The G-CNN model is trained by mapping an initial time state to a future prediction time state; consequently, the model can be used for generalizing predictions in any grid sizes and time steps while maintaining accuracy. The result is a computationally and memory efficient neural network that can be iterated and queried to reproduce a reservoir simulation.\u0000 This novel methodology combines field-scale physics-based reservoir modeling and DNN for reservoir simulations. The new reservoir simulation workflow, based on the G-CNN model, maps the time state predictions in a resampled grid, reducing computational time and memory. The new methodology presents a general method for compressing reservoir simulations, assisting in fast and accurate prod","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"88 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"78174949","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}
E. Sayapov, A. Nunez, I. Farei, Ahmed Benchekor, Osama Hazzaa, Tarik Mesbahi, Matthew Thomson, Kyle Strom
In current depressed oilfield industry environment, economical and operational effectiveness becomes even more important especially in complicated, challenging projects that demand large investments and simultaneous utilization of multiple technical services. In Petroleum Development Oman (PDO), there are a few gas fields having similar downhole conditions with multiple target pay zones, whereas fracturing operations are complicated by the requirement of CT cleanouts and/or milling in between the stages. Multizonal and multistage frac operations are commonplace in oil and gas reserves around the globe, however despite of increased number of wells stimulated using specialist multistage completion equipment, the most often utilized completion design for this operation is still plug and perf, especially in vertical wells. There are also techniques on the market involving coiled tubing for perforation and isolation between the stages, however they have their own constraints and limitations, especially in high-pressure and high-temperature environment. For PDO wells, multistage completion technologies were not feasible, therefore conventional plug & perf approach had been selected as the optimum option. The main drivers behind this selection are the challenges associated with precise deployment of the completion jewellery across small pay zones and limited coverage of the target zones when using frac sleeves. Another constraint in the past was the pressure rating of the multistage completion systems existed on the market. Plug and perf completions are designed to allow pinpoint placement of isolation and reservoir access with on the fly adjustability. This means that there is more freedom in selecting desired perforation interval, plug-setting depth and no additional restrictions on the pumping rates that are incurred by CT string inside the tubing as in some of the popular techniques. The zonal isolation is the portion of the design that allows the frac treatment to address the target intervals without affecting the others. In operations requiring 15k+ differential pressure ratings, isolation becomes extremely challenging and requires robust and reliable technology to ensure true integrity so stimulations can be placed as per design. This challenge may get even worse with increasing temperatures, whereas conventional composite compounds are not applicable due to "swelling", or getting softer. The primary job of the frac plug is to isolate but operational safety and millability also must be taken into consideration for the overall efficiency of a completion design. Additional challenges in the target fields are the depletion of the zones and their extreme breakdown pressures that are not only exposing frac plugs to extreme differential stresses but also causing difficulties during milling operations, whereas maintaining balanced circulation becomes a primary task in order to prevent coiled tubing differentially or mechanically sticking in the wellb
{"title":"Multistage Frac Zonal Isolation in Extreme HPHT Conditions - Solution to Succeed","authors":"E. Sayapov, A. Nunez, I. Farei, Ahmed Benchekor, Osama Hazzaa, Tarik Mesbahi, Matthew Thomson, Kyle Strom","doi":"10.2118/197653-ms","DOIUrl":"https://doi.org/10.2118/197653-ms","url":null,"abstract":"\u0000 In current depressed oilfield industry environment, economical and operational effectiveness becomes even more important especially in complicated, challenging projects that demand large investments and simultaneous utilization of multiple technical services. In Petroleum Development Oman (PDO), there are a few gas fields having similar downhole conditions with multiple target pay zones, whereas fracturing operations are complicated by the requirement of CT cleanouts and/or milling in between the stages. Multizonal and multistage frac operations are commonplace in oil and gas reserves around the globe, however despite of increased number of wells stimulated using specialist multistage completion equipment, the most often utilized completion design for this operation is still plug and perf, especially in vertical wells. There are also techniques on the market involving coiled tubing for perforation and isolation between the stages, however they have their own constraints and limitations, especially in high-pressure and high-temperature environment. For PDO wells, multistage completion technologies were not feasible, therefore conventional plug & perf approach had been selected as the optimum option. The main drivers behind this selection are the challenges associated with precise deployment of the completion jewellery across small pay zones and limited coverage of the target zones when using frac sleeves. Another constraint in the past was the pressure rating of the multistage completion systems existed on the market.\u0000 Plug and perf completions are designed to allow pinpoint placement of isolation and reservoir access with on the fly adjustability. This means that there is more freedom in selecting desired perforation interval, plug-setting depth and no additional restrictions on the pumping rates that are incurred by CT string inside the tubing as in some of the popular techniques. The zonal isolation is the portion of the design that allows the frac treatment to address the target intervals without affecting the others. In operations requiring 15k+ differential pressure ratings, isolation becomes extremely challenging and requires robust and reliable technology to ensure true integrity so stimulations can be placed as per design. This challenge may get even worse with increasing temperatures, whereas conventional composite compounds are not applicable due to \"swelling\", or getting softer. The primary job of the frac plug is to isolate but operational safety and millability also must be taken into consideration for the overall efficiency of a completion design. Additional challenges in the target fields are the depletion of the zones and their extreme breakdown pressures that are not only exposing frac plugs to extreme differential stresses but also causing difficulties during milling operations, whereas maintaining balanced circulation becomes a primary task in order to prevent coiled tubing differentially or mechanically sticking in the wellb","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"175 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77714398","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}
Failure investigation of 12″(305 mm) high pressure steel welded pipe was carried out in this study using ASTM standards in all mechanical and metallurgical tests. Visual inspections was done immediately after receiving the failed pipe section. The pipe was then cut at approximately the center position of the failed-welded joint showing a circumferential crack at the joint along half of the outer surface periphery of the pipe. Tensile, hardness, chemical and microstructural analyses were performed on samples taken at different orientation of the pipe and the weld. Optical emission spectrometer were used to obtain chemical composition of samples. Microstructure testing of surfaces were prepared using grinding, polishing and etching. SEM was used to study failure at high magnification. Root cause of failure was found to be due to combination of operating conditions, oxidation cyclic stresses, and depletion of chromium in the matrix near grain boundaries, methods to reduce corrosion were discussed.
{"title":"Steam Pipeline Weld Failure Analysis.","authors":"A. Elkholy, Amani Al Banoon","doi":"10.2118/197148-MS","DOIUrl":"https://doi.org/10.2118/197148-MS","url":null,"abstract":"\u0000 Failure investigation of 12″(305 mm) high pressure steel welded pipe was carried out in this study using ASTM standards in all mechanical and metallurgical tests. Visual inspections was done immediately after receiving the failed pipe section. The pipe was then cut at approximately the center position of the failed-welded joint showing a circumferential crack at the joint along half of the outer surface periphery of the pipe. Tensile, hardness, chemical and microstructural analyses were performed on samples taken at different orientation of the pipe and the weld. Optical emission spectrometer were used to obtain chemical composition of samples. Microstructure testing of surfaces were prepared using grinding, polishing and etching. SEM was used to study failure at high magnification. Root cause of failure was found to be due to combination of operating conditions, oxidation cyclic stresses, and depletion of chromium in the matrix near grain boundaries, methods to reduce corrosion were discussed.","PeriodicalId":11061,"journal":{"name":"Day 1 Mon, November 11, 2019","volume":"39 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2019-11-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73626295","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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