Tamir Abo El Nour, T. Bodewes, M. Wharton, C. Verlaan
The objectives of the paper are to use the Basrah NGL gas processing project in the Basrah Gas Company JV (BGC) to demonstrate best practice application of industry solutions and appropriate technology selection, aligning with project value drivers whilst managing technical and non-technical uncertainties in decision making. In mid-2018 contracts were awarded for the Basrah NGL gas processing hub in Southern Iraq that will set the competitive cost and schedule benchmark for new gas plants in Iraq. Embracing Shell and industry experience to deliver a standardized and replicable design was a key priority for the project team and JV partners. Technology selections were evaluated against project value drivers to support robust decision making for current and future operations, and contracting strategy selected considering synergies across the portfolio through bundling and building on in-country experience. Two trains of 200 mmscf/d each have been awarded in the first development phase, however future expansion requirements are much simplified with the facility designed to be expandable to 5 replicated trains providing a total 1000 mmscf/d capacity in line with the upstream gas production forecast. The benefits of standardisation and replication lock in further cost and schedule savings for subsequent gas processing trains and continue to lower unit development and operating costs. In line with the future plans for the facilities, pre-investments were made for major infrastructure investments including gas and LPG export pipelines and high voltage power supply. The BGC NGL processing train design is flexible to the range of gas qualities prevalent in Southern Iraq. Technology selections have been appropriately made to consider current and future requirements both in terms of ethane and LPG recovery but also acid gas removal and Sulphur recovery solutions. In the case of Sulphur recovery, a Shell and-Paques developed, Thiopaq technology is selected to provide the most capital efficient flexible solution, whilst also providing ease of scale-up to higher recovery rates as the upstream gas supply becomes progressively more sour (with higher H2S content) over time.
{"title":"Basrah NGL: Best Practices for a New Sour Gas Processing Hub in Southern Iraq","authors":"Tamir Abo El Nour, T. Bodewes, M. Wharton, C. Verlaan","doi":"10.2118/193228-MS","DOIUrl":"https://doi.org/10.2118/193228-MS","url":null,"abstract":"\u0000 The objectives of the paper are to use the Basrah NGL gas processing project in the Basrah Gas Company JV (BGC) to demonstrate best practice application of industry solutions and appropriate technology selection, aligning with project value drivers whilst managing technical and non-technical uncertainties in decision making.\u0000 In mid-2018 contracts were awarded for the Basrah NGL gas processing hub in Southern Iraq that will set the competitive cost and schedule benchmark for new gas plants in Iraq. Embracing Shell and industry experience to deliver a standardized and replicable design was a key priority for the project team and JV partners. Technology selections were evaluated against project value drivers to support robust decision making for current and future operations, and contracting strategy selected considering synergies across the portfolio through bundling and building on in-country experience.\u0000 Two trains of 200 mmscf/d each have been awarded in the first development phase, however future expansion requirements are much simplified with the facility designed to be expandable to 5 replicated trains providing a total 1000 mmscf/d capacity in line with the upstream gas production forecast. The benefits of standardisation and replication lock in further cost and schedule savings for subsequent gas processing trains and continue to lower unit development and operating costs. In line with the future plans for the facilities, pre-investments were made for major infrastructure investments including gas and LPG export pipelines and high voltage power supply.\u0000 The BGC NGL processing train design is flexible to the range of gas qualities prevalent in Southern Iraq. Technology selections have been appropriately made to consider current and future requirements both in terms of ethane and LPG recovery but also acid gas removal and Sulphur recovery solutions. In the case of Sulphur recovery, a Shell and-Paques developed, Thiopaq technology is selected to provide the most capital efficient flexible solution, whilst also providing ease of scale-up to higher recovery rates as the upstream gas supply becomes progressively more sour (with higher H2S content) over time.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"45 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"73910654","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. Alkindi, D. Mahrouqi, Safa Baqlani, Inaki Llaguno, R. Mjeni, Majid Mahrooqi, M. Nadeem
The Marmul inverted five-spot pilot was successfully completed in 2016, demonstrating the effectiveness of Alkaline Surfactant Polymer (ASP) flooding in improving oil recovery from Al khalata reservoir. Earlier studies including core flood experiments, single well chemical tracer tests and small scale models indicated a potential of >10% of ASP incremental recovery over polymer flood and >20% over water flood. The pilot included a custom-built ASP facility, a first of its kind of scale squeeze treatment for high pH, state-of-the-art nuclear magnetic resonance (NMR) technology for vertical saturation estimates and very extensive sampling and surveillance programme. Overall, the pilot operation was very smooth and stable, achieving high facility uptime, good injectivity, accurate chemical dosing and met the surveillance target. The estimated ASP incremental recovery from the pilot was over 30%, which increased the interest in a field-wide ASP injection. The acquired pilot results and operation experience were used to scale up the facilities design and assess the impact of key uncertainties observed in the field and the lab. Major factors influencing the recovery factor and project efficiency were analysed including chemicals formulation, facilities design and water treatment technologies. A mind-shift on the formulation cocktail and facilities design was proposed to improve the economic attractiveness of the process on large scale implementations. A phased development is proposed to de-risk subsurface and surface concepts which are different from those in the pilot. This paper discusses in brief the pilot operation & performance, scaling up the results to full field implementation and key design considerations for a cost effective ASP project.
{"title":"ASP Journey, from Pilot to Full Field Implementation in South of the Sultanate of Oman","authors":"A. Alkindi, D. Mahrouqi, Safa Baqlani, Inaki Llaguno, R. Mjeni, Majid Mahrooqi, M. Nadeem","doi":"10.2118/193177-MS","DOIUrl":"https://doi.org/10.2118/193177-MS","url":null,"abstract":"\u0000 The Marmul inverted five-spot pilot was successfully completed in 2016, demonstrating the effectiveness of Alkaline Surfactant Polymer (ASP) flooding in improving oil recovery from Al khalata reservoir. Earlier studies including core flood experiments, single well chemical tracer tests and small scale models indicated a potential of >10% of ASP incremental recovery over polymer flood and >20% over water flood. The pilot included a custom-built ASP facility, a first of its kind of scale squeeze treatment for high pH, state-of-the-art nuclear magnetic resonance (NMR) technology for vertical saturation estimates and very extensive sampling and surveillance programme. Overall, the pilot operation was very smooth and stable, achieving high facility uptime, good injectivity, accurate chemical dosing and met the surveillance target.\u0000 The estimated ASP incremental recovery from the pilot was over 30%, which increased the interest in a field-wide ASP injection. The acquired pilot results and operation experience were used to scale up the facilities design and assess the impact of key uncertainties observed in the field and the lab. Major factors influencing the recovery factor and project efficiency were analysed including chemicals formulation, facilities design and water treatment technologies. A mind-shift on the formulation cocktail and facilities design was proposed to improve the economic attractiveness of the process on large scale implementations. A phased development is proposed to de-risk subsurface and surface concepts which are different from those in the pilot.\u0000 This paper discusses in brief the pilot operation & performance, scaling up the results to full field implementation and key design considerations for a cost effective ASP project.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"87 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"84227218","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}
Amit Kumar, Manish Srivastava, A. Shehhi, T. A. Daghar, Walid Abdulhai, C. Gan
Most of the existing wells in a giant oil offshore field in Abu Dhabi are equipped with L80-13Cr corrosion resistant alloy (CRA) tubulars to provide protection from CO2 corrosion due to sweet nature of reservoir. Recently, some of the wells are showing a presence of mild H2S due to unexpected reservoir souring or other geological changes. The presence of H2S in production fluids raises concerns about sulfide-stress-cracking (SSC) of L80-13Cr. As L80-13Cr CRA has been known to have limited SSC resistance, it is important to understand the maximum acceptable limit of H2S in production fluids for safe operation. Industry standards such as ISO15156/ NACE MR0175 and NORSOK-M-001 recommend safe acceptable limits of H2S for 13Cr tubular materials based on the partial pressure of H2S. However, these approaches do not take into account the effect of temperature, or non-ideal gas behavior of H2S at high pressure. Pressure, temperature, salinity and pH in the wellbore impact the solubility and chemical behavior of H2S in the water phase which defines the corrosive environment to which the material is exposed. Therefore, it is important to include non-ideal gas and solution behaviors in order to define the acceptable limit of H2S for fitness-for-service (FFS) material evaluations. In this work the acceptable limit of H2S in the wellbore was determined using a combination of thermodynamic modeling and field corrosion data. A molecular thermodynamics approach was used to calculate pH and dissolved H2S levels in water along the production tubing length. Shut-in and production operation scenarios were simulated to identify the worst-case scenario using thermal modeling software. Furthermore, tubing inspections were conducted using a multi-finger caliper tool to identify any corrosion damage. All of this information was used to identify the acceptable limit for H2S in the wellbore. This approach to determining acceptable H2S limits will avoid unnecessary workovers and enables cost saving through continued use of existing materials. Furthermore, it supports the development of a corrosion monitoring plan, and FFS assessment of tubulars based on the wellbore environment.
{"title":"Fit-For-Service Qualification of Existing 13Cr Tubulars in Mildly Sour Wells Based on Thermodynamic Approach","authors":"Amit Kumar, Manish Srivastava, A. Shehhi, T. A. Daghar, Walid Abdulhai, C. Gan","doi":"10.2118/192947-MS","DOIUrl":"https://doi.org/10.2118/192947-MS","url":null,"abstract":"\u0000 Most of the existing wells in a giant oil offshore field in Abu Dhabi are equipped with L80-13Cr corrosion resistant alloy (CRA) tubulars to provide protection from CO2 corrosion due to sweet nature of reservoir. Recently, some of the wells are showing a presence of mild H2S due to unexpected reservoir souring or other geological changes. The presence of H2S in production fluids raises concerns about sulfide-stress-cracking (SSC) of L80-13Cr. As L80-13Cr CRA has been known to have limited SSC resistance, it is important to understand the maximum acceptable limit of H2S in production fluids for safe operation.\u0000 Industry standards such as ISO15156/ NACE MR0175 and NORSOK-M-001 recommend safe acceptable limits of H2S for 13Cr tubular materials based on the partial pressure of H2S. However, these approaches do not take into account the effect of temperature, or non-ideal gas behavior of H2S at high pressure. Pressure, temperature, salinity and pH in the wellbore impact the solubility and chemical behavior of H2S in the water phase which defines the corrosive environment to which the material is exposed. Therefore, it is important to include non-ideal gas and solution behaviors in order to define the acceptable limit of H2S for fitness-for-service (FFS) material evaluations.\u0000 In this work the acceptable limit of H2S in the wellbore was determined using a combination of thermodynamic modeling and field corrosion data. A molecular thermodynamics approach was used to calculate pH and dissolved H2S levels in water along the production tubing length. Shut-in and production operation scenarios were simulated to identify the worst-case scenario using thermal modeling software. Furthermore, tubing inspections were conducted using a multi-finger caliper tool to identify any corrosion damage. All of this information was used to identify the acceptable limit for H2S in the wellbore. This approach to determining acceptable H2S limits will avoid unnecessary workovers and enables cost saving through continued use of existing materials. Furthermore, it supports the development of a corrosion monitoring plan, and FFS assessment of tubulars based on the wellbore environment.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"6 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82154508","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}
T. Beebe, Jose H. Vazquez, J. Rousseau, Lars Samuelsson, Pete Cunnion, Clay Coan
The goal is to define conditions under which a GustoMSC CJ46-X100-D jackup rig designed for unrestricted service can be rated for full operational drilling capabilities in areas with a relatively weak soil top layer and a more benign environment. The GustoMSC CJ46-X100-D jackup rig is designed with environmental criteria derived from the southern North Sea and a bearing pressure of 53.5 MT/m2 (10.96 ksf); however, the maximum soil bearing pressure in some areas of the Arabian Gulf and elsewhere cannot exceed 41.5 MT/m2 (8.5 ksf).
{"title":"Alternative Operation Scheme for a Jackup Drilling Rig to Meet Target Soil Bearing Pressure Requirements","authors":"T. Beebe, Jose H. Vazquez, J. Rousseau, Lars Samuelsson, Pete Cunnion, Clay Coan","doi":"10.2118/193287-MS","DOIUrl":"https://doi.org/10.2118/193287-MS","url":null,"abstract":"\u0000 The goal is to define conditions under which a GustoMSC CJ46-X100-D jackup rig designed for unrestricted service can be rated for full operational drilling capabilities in areas with a relatively weak soil top layer and a more benign environment. The GustoMSC CJ46-X100-D jackup rig is designed with environmental criteria derived from the southern North Sea and a bearing pressure of 53.5 MT/m2 (10.96 ksf); however, the maximum soil bearing pressure in some areas of the Arabian Gulf and elsewhere cannot exceed 41.5 MT/m2 (8.5 ksf).","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"46 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"82310354","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}
H. Xian, Austin Anaevune, C. Anijekwu, Mbursa J. Nayagawa, Stella Ihuoma Egwim, V. Longe, Nduka Ezechukwu, Robert Lee, I. Hulea
Novel interpretation approaches for remaining hydrocarbon saturation evaluation were developed from our study and presented in this paper. Innovative power law relationships and algorithms are used for evaluating oil saturation from Carbon/Oxygen (C/O) logs and gas saturation from capture-to-inelastic count rate ratios, based on the principle of the modern multi-detector pulsed neutron tool responses and the total porosity rock model. C/O log interpretation parameters are determined from the crossplot of near detector against far detector C/O logs, and gas saturation interpretation parameters are obtained from the crossplot of near detector versus far detector capture-to-inelastic count rate ratios. An alternative fixed response line method is proposed based on a simplified C/O log response rock model. Integrated interpretation is applied through the post processing combining the interpretations of C/O logs and capture-to-inelastic count rate ratios, to derive the final result. The developed approaches have been applied to wells from Nigeria Delta and North Sea. Example results have successfully demonstrated greater advantages over the traditional methodologies. These new approaches have markedly reduced the saturation uncertainty related to wellbore effects, especially for wells with complex well completions and borehole fluid phase change. These results were subsequently useful information for the dynamic reservoir simulation models.
{"title":"Novel Approaches for Remaining Hydrocarbon Saturation Evaluation Through Interpretation of Multi-Detector Pulsed Neutron Logs","authors":"H. Xian, Austin Anaevune, C. Anijekwu, Mbursa J. Nayagawa, Stella Ihuoma Egwim, V. Longe, Nduka Ezechukwu, Robert Lee, I. Hulea","doi":"10.2118/192730-MS","DOIUrl":"https://doi.org/10.2118/192730-MS","url":null,"abstract":"\u0000 Novel interpretation approaches for remaining hydrocarbon saturation evaluation were developed from our study and presented in this paper. Innovative power law relationships and algorithms are used for evaluating oil saturation from Carbon/Oxygen (C/O) logs and gas saturation from capture-to-inelastic count rate ratios, based on the principle of the modern multi-detector pulsed neutron tool responses and the total porosity rock model. C/O log interpretation parameters are determined from the crossplot of near detector against far detector C/O logs, and gas saturation interpretation parameters are obtained from the crossplot of near detector versus far detector capture-to-inelastic count rate ratios. An alternative fixed response line method is proposed based on a simplified C/O log response rock model. Integrated interpretation is applied through the post processing combining the interpretations of C/O logs and capture-to-inelastic count rate ratios, to derive the final result.\u0000 The developed approaches have been applied to wells from Nigeria Delta and North Sea. Example results have successfully demonstrated greater advantages over the traditional methodologies. These new approaches have markedly reduced the saturation uncertainty related to wellbore effects, especially for wells with complex well completions and borehole fluid phase change. These results were subsequently useful information for the dynamic reservoir simulation models.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"19 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"83997841","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
To better understand local displacement efficiency, direct numerical simulations of water-flooding in a mixed-wet rock from a producing reservoir were performed using the multiphase Lattice Boltzmann (LB) method. Experimentally measured contact angles (AlRatrout et al., 2017) were incorporated into the simulation models using our previously reported wetting boundary condition for the LB method (Akai et al., 2018b). The simulation model was calibrated by comparing pore occupancy and fluid conductivity with results from an experimental water-flooding study where the fluid configurations were imaged at a resolution of a few microns (Alhammadi et al., 2017, 2018). Furthermore, to investigate the impact of several enhanced oil recovery (EOR) schemes on recovery, the calibrated simulation model was also used for a sensitivity study. Taking the calibrated model as a base case, three EOR cases were investigated; low salinity water-flooding, surfactant flooding and polymer flooding. For low salinity water-flooding, the wettability of pore walls was changed to be more water-wet than that of the base case. For surfactant flooding, the interfacial tension was reduced. For polymer flooding, the viscosity of injection water was increased. A significant change in oil recovery factor was observed in these cases. These results make it possible to better understand the impact of EOR schemes on microscopic recovery. We demonstrate the predictive power of our direct numerical simulation by presenting comparisons of the fluid distribution at the pore-scale between the experiment and simulation. Then, we show how direct numerical simulation helps understand EOR schemes. This work provides a comprehensive workflow for pore-scale modeling from experiments to modeling.
{"title":"Direct Multiphase Numerical Simulation on Mixed-Wet Reservoir Carbonates","authors":"Takashi Akai, A. Alhammadi, M. Blunt, B. Bijeljic","doi":"10.2118/193323-MS","DOIUrl":"https://doi.org/10.2118/193323-MS","url":null,"abstract":"\u0000 To better understand local displacement efficiency, direct numerical simulations of water-flooding in a mixed-wet rock from a producing reservoir were performed using the multiphase Lattice Boltzmann (LB) method. Experimentally measured contact angles (AlRatrout et al., 2017) were incorporated into the simulation models using our previously reported wetting boundary condition for the LB method (Akai et al., 2018b). The simulation model was calibrated by comparing pore occupancy and fluid conductivity with results from an experimental water-flooding study where the fluid configurations were imaged at a resolution of a few microns (Alhammadi et al., 2017, 2018). Furthermore, to investigate the impact of several enhanced oil recovery (EOR) schemes on recovery, the calibrated simulation model was also used for a sensitivity study. Taking the calibrated model as a base case, three EOR cases were investigated; low salinity water-flooding, surfactant flooding and polymer flooding. For low salinity water-flooding, the wettability of pore walls was changed to be more water-wet than that of the base case. For surfactant flooding, the interfacial tension was reduced. For polymer flooding, the viscosity of injection water was increased. A significant change in oil recovery factor was observed in these cases. These results make it possible to better understand the impact of EOR schemes on microscopic recovery. We demonstrate the predictive power of our direct numerical simulation by presenting comparisons of the fluid distribution at the pore-scale between the experiment and simulation. Then, we show how direct numerical simulation helps understand EOR schemes. This work provides a comprehensive workflow for pore-scale modeling from experiments to modeling.","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":"80601924","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}
T. Ishiyama, Mohammed Y. Ali, G. Blacquière, S. Nakayama
Recently, we established a generalized blending model, which can explain any methods of blended acquisition by including the encoding into the generalized operators. With this highly flexible and tolerant model, we come up with a challenging question: what it is to be, and how to find an optimal blended-acquisition design, which should be the most suitable for deblended-data reconstruction among plenty of concepts of blended acquisition. In this paper, we introduce a method of blended-acquisition encoding: temporally modulated and spatially dispersed source array, namely M-DSA, that jointly uses modulation sequencing in the time dimension and dispersed source array in the space dimension. This allows quite straightforward deblending by filtering and physically separating frequency channels in the frequency domain. We run our blended-acquisition designing based on the deblending performance for several scenarios of blended acquisition. These examples show that: M-DSA attains the best deblending performance; this method has less constraints in the encoding with more operational flexibility, compared to other methods being developed in the industry today. Indeed, this method requires only simple signaturing in the encoding; merely frequency-banded and modulated signatures in the time dimension for each shot in the blended-source array. This could even render any other blending properties unnecessary. Those, such as distance separation among shot locations and time shifts among shot times, might not be required anymore. There might be no limitation on the number of sources, thus no limitation on the blending fold, in order to secure successful deblending. Furthermore, this method allows random sampling; randomly distributed sources in the space dimension in the blended-source array. Consequently, this method makes the blended-acquisition encoding and operations significantly simple and robust, as well as for the deblending processing. We believe that our M-DSA method should be one of the best methods of blended acquisition.
{"title":"Blended-Acquisition Encoding with Generalized Blending Operators: Signaturing with Temporally Amplitude-Modulated and Spatially Dispersed Source Array","authors":"T. Ishiyama, Mohammed Y. Ali, G. Blacquière, S. Nakayama","doi":"10.2118/192777-MS","DOIUrl":"https://doi.org/10.2118/192777-MS","url":null,"abstract":"\u0000 Recently, we established a generalized blending model, which can explain any methods of blended acquisition by including the encoding into the generalized operators. With this highly flexible and tolerant model, we come up with a challenging question: what it is to be, and how to find an optimal blended-acquisition design, which should be the most suitable for deblended-data reconstruction among plenty of concepts of blended acquisition. In this paper, we introduce a method of blended-acquisition encoding: temporally modulated and spatially dispersed source array, namely M-DSA, that jointly uses modulation sequencing in the time dimension and dispersed source array in the space dimension. This allows quite straightforward deblending by filtering and physically separating frequency channels in the frequency domain.\u0000 We run our blended-acquisition designing based on the deblending performance for several scenarios of blended acquisition. These examples show that: M-DSA attains the best deblending performance; this method has less constraints in the encoding with more operational flexibility, compared to other methods being developed in the industry today. Indeed, this method requires only simple signaturing in the encoding; merely frequency-banded and modulated signatures in the time dimension for each shot in the blended-source array. This could even render any other blending properties unnecessary. Those, such as distance separation among shot locations and time shifts among shot times, might not be required anymore. There might be no limitation on the number of sources, thus no limitation on the blending fold, in order to secure successful deblending. Furthermore, this method allows random sampling; randomly distributed sources in the space dimension in the blended-source array. Consequently, this method makes the blended-acquisition encoding and operations significantly simple and robust, as well as for the deblending processing. We believe that our M-DSA method should be one of the best methods of blended acquisition.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"431 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"77813416","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}
Mohamed Abdel-Basset, Mishal Al-Mufarej, M. Al-Mutawa, H. Chetri, E. Anthony, H. Alzaabi, Nelson Bolanos, H. Ruiz, K. Harami
This paper demonstrates the production optimization methodology being used by Kuwait Oil Company to increase production in one of its giant and mature fields by 18% over 5.0 years. Production optimization is a continuous iterative process to improve production, especially in mature fields. The North Kuwait Redevelopment team has adopted an integrated enhanced and structured process to identify opportunities for production optimization with a pro-active approach focusing on flowing wells and rig-less interventions to tackle production challenges and achieve production targets Typical mature-field challenges are present. These include water flooding, produced water management, artificial lift, with more than 1000 (vertical, deviated and horizontal) active wells, coupled with high structure complexity and stratigraphic heterogeneity, tight sandstone and carbonate reservoirs, shortage of work-over rigs. These challenges make the field appropriate to apply the production optimization methodology outlined here. The Heterogeneity Index (HI) process is utilized to rapidly demonstrate production gain opportunities, for a giant mature North Kuwait Sabria field of approximately 1000 wells produce from different reservoirs. The HI process provided a quick screening method of identifying preliminary candidate wells with anomalous behavior (over/under performance) for further analysis and most importantly, provided the foundation for the overall structured production approach. The results from this screening tool were utilized to identify the families of type productivity problems at field and well levels with solution categories for production enhancement. Representative wells were selected for detailed diagnostics based on the relevance and size of productivity impact and the potential of its well deliverability. Once a few "top potential" wells were identified, production engineering workflows were implemented to assess and forecast the potential of production increase and to determine and evaluate the best intervention action. This production optimization workflow is done in a consistent cycled process considering the ageing condition of the mature field, and the aforementioned challenges. Approximately 35% of the wells have been selected for further analysis over multiple production optimization cycles spanning approximately 5.0 years. A detailed production engineering workflow provided recommendations of various remedial intervention solutions to improve well production potential via productivity enhancement, water shut-off/conformance, stimulation, additional and/or re-perforations, and Artificial lift optimization. Other advanced technologies were applied to improve various strategies, including completions, perforation, stimulation, and injection/production control. To date (Febrauary, 2018), recommendations for approximately 30% (300) wells have been executed, with a significant oil gain of approximately 18 % of the total field production.
{"title":"Integrated Production Optimization Workflow Provides Robust Platform for Significant Oil Gain to a Mature Oilfield","authors":"Mohamed Abdel-Basset, Mishal Al-Mufarej, M. Al-Mutawa, H. Chetri, E. Anthony, H. Alzaabi, Nelson Bolanos, H. Ruiz, K. Harami","doi":"10.2118/193121-MS","DOIUrl":"https://doi.org/10.2118/193121-MS","url":null,"abstract":"\u0000 This paper demonstrates the production optimization methodology being used by Kuwait Oil Company to increase production in one of its giant and mature fields by 18% over 5.0 years.\u0000 Production optimization is a continuous iterative process to improve production, especially in mature fields. The North Kuwait Redevelopment team has adopted an integrated enhanced and structured process to identify opportunities for production optimization with a pro-active approach focusing on flowing wells and rig-less interventions to tackle production challenges and achieve production targets\u0000 Typical mature-field challenges are present. These include water flooding, produced water management, artificial lift, with more than 1000 (vertical, deviated and horizontal) active wells, coupled with high structure complexity and stratigraphic heterogeneity, tight sandstone and carbonate reservoirs, shortage of work-over rigs. These challenges make the field appropriate to apply the production optimization methodology outlined here.\u0000 The Heterogeneity Index (HI) process is utilized to rapidly demonstrate production gain opportunities, for a giant mature North Kuwait Sabria field of approximately 1000 wells produce from different reservoirs. The HI process provided a quick screening method of identifying preliminary candidate wells with anomalous behavior (over/under performance) for further analysis and most importantly, provided the foundation for the overall structured production approach. The results from this screening tool were utilized to identify the families of type productivity problems at field and well levels with solution categories for production enhancement. Representative wells were selected for detailed diagnostics based on the relevance and size of productivity impact and the potential of its well deliverability. Once a few \"top potential\" wells were identified, production engineering workflows were implemented to assess and forecast the potential of production increase and to determine and evaluate the best intervention action.\u0000 This production optimization workflow is done in a consistent cycled process considering the ageing condition of the mature field, and the aforementioned challenges.\u0000 Approximately 35% of the wells have been selected for further analysis over multiple production optimization cycles spanning approximately 5.0 years. A detailed production engineering workflow provided recommendations of various remedial intervention solutions to improve well production potential via productivity enhancement, water shut-off/conformance, stimulation, additional and/or re-perforations, and Artificial lift optimization. Other advanced technologies were applied to improve various strategies, including completions, perforation, stimulation, and injection/production control. To date (Febrauary, 2018), recommendations for approximately 30% (300) wells have been executed, with a significant oil gain of approximately 18 % of the total field production.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"13 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"90841393","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}
Energy management and fuel conservation are crucial for controlling emissions and enhancing profitability of today’s oil and gas industries. Many organization are pursuing flaring and emission reduction initiative as part of their energy management system thereby minimizing operating cost and liberation of harmful greenhouse gases to the environment. This paper presents a flaring and emission reduction initiative implemented at ADNOC Gas Processing natural gas liquids (NGL) fractionation plants in Ruwais. The design limitations on spent gas piping system leading to loss of valuable of fuel gas resources were recovered by enhancing the capability of the system. Following is the list of actions completed to implement the initiative:Feasibility study for utilization of flared spent regeneration gases as fuel gases for boilersUpgradation of spent gas piping for sour serviceApplying an innovative non-linear fuel blending controller The successful implementation of the initiative by in-house team resulted in an impressive flaring reduction of 60% and a reduction of CO2 emissions of 62,700 Tons/annum.
{"title":"Reduce Emissions and Save Energy by Converting Flared Gases into Fuel Gases","authors":"Venugopal Bakthavachsalam, Sevideen Abdul Shathar","doi":"10.2118/193071-MS","DOIUrl":"https://doi.org/10.2118/193071-MS","url":null,"abstract":"\u0000 Energy management and fuel conservation are crucial for controlling emissions and enhancing profitability of today’s oil and gas industries. Many organization are pursuing flaring and emission reduction initiative as part of their energy management system thereby minimizing operating cost and liberation of harmful greenhouse gases to the environment.\u0000 This paper presents a flaring and emission reduction initiative implemented at ADNOC Gas Processing natural gas liquids (NGL) fractionation plants in Ruwais. The design limitations on spent gas piping system leading to loss of valuable of fuel gas resources were recovered by enhancing the capability of the system.\u0000 Following is the list of actions completed to implement the initiative:Feasibility study for utilization of flared spent regeneration gases as fuel gases for boilersUpgradation of spent gas piping for sour serviceApplying an innovative non-linear fuel blending controller\u0000 The successful implementation of the initiative by in-house team resulted in an impressive flaring reduction of 60% and a reduction of CO2 emissions of 62,700 Tons/annum.","PeriodicalId":11208,"journal":{"name":"Day 2 Tue, November 13, 2018","volume":"48 1","pages":""},"PeriodicalIF":0.0,"publicationDate":"2018-11-12","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"85917970","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}
ADNOC's proactive response to worldwide changes affecting the industry is to enhance operational efficiencies, optimize costs and improve performance. The ATI (ADNOC Technical Institute) to ATA (ADNOC Technical Academy) transformation project is part of this response and aims to provide ADNOC with a sustainable workforce to run its business by applying an approach to training that is based on competency and performance, and where OJT (On the Job Training) plays a crucial role. The major achievements of the transformation after the first year of its implementation are: –Implement a new curriculum that is shorter, more efficient and fully aligned with end-user needs and expectations.–Rationalize practices to optimize costs, implementing a high performance-driven culture that values good work habits and improve attitudes and commitment to HSE.–Strong efforts in rehabilitating the large majority of existing trainees (84%) to "jump the curve" and make it to the new program despite the enhanced requirements–Instil a culture whereupon students are trained to understand the importance of being accountable, working in a team, communicating effectively with others, taking initiative, knowing their strengths, building goals and ambitions and working hard to overcome their identified weaknesses.–Engaging 9 operating companies to accommodate 400 trainees on their 13 sites for OJT–Change in organizational culture by which staff and students are accountable and responsible to meet specific performance standards.–Provide re-skilling solution for existing developpees facing difficulties in finalizing their full integration to operational staff by developing a pre-program. Further to the development of technical competence, the new program strives to contribute to the development of mature and responsible attitudes amongst our graduates, in view of a successful integration within ADNOC workforce. The first trainees will graduate in March 2019 and will integrate ADNOC Group Companies (GCs). A priority is finalizing the work of the Assessment and Competency Development Centre in identifying the competency gaps of existing operators and technicians and addressing them through proper solutions. ATA is working now to maximize its intake capacity and deliver 600 graduates per year as well as getting the program accredited to the diploma level.
{"title":"From ATI to ATA: Building the Next Generation of Operators and Technicians","authors":"Stéphane Laurent","doi":"10.2118/193227-MS","DOIUrl":"https://doi.org/10.2118/193227-MS","url":null,"abstract":"\u0000 ADNOC's proactive response to worldwide changes affecting the industry is to enhance operational efficiencies, optimize costs and improve performance. The ATI (ADNOC Technical Institute) to ATA (ADNOC Technical Academy) transformation project is part of this response and aims to provide ADNOC with a sustainable workforce to run its business by applying an approach to training that is based on competency and performance, and where OJT (On the Job Training) plays a crucial role.\u0000 The major achievements of the transformation after the first year of its implementation are: –Implement a new curriculum that is shorter, more efficient and fully aligned with end-user needs and expectations.–Rationalize practices to optimize costs, implementing a high performance-driven culture that values good work habits and improve attitudes and commitment to HSE.–Strong efforts in rehabilitating the large majority of existing trainees (84%) to \"jump the curve\" and make it to the new program despite the enhanced requirements–Instil a culture whereupon students are trained to understand the importance of being accountable, working in a team, communicating effectively with others, taking initiative, knowing their strengths, building goals and ambitions and working hard to overcome their identified weaknesses.–Engaging 9 operating companies to accommodate 400 trainees on their 13 sites for OJT–Change in organizational culture by which staff and students are accountable and responsible to meet specific performance standards.–Provide re-skilling solution for existing developpees facing difficulties in finalizing their full integration to operational staff by developing a pre-program.\u0000 Further to the development of technical competence, the new program strives to contribute to the development of mature and responsible attitudes amongst our graduates, in view of a successful integration within ADNOC workforce. The first trainees will graduate in March 2019 and will integrate ADNOC Group Companies (GCs).\u0000 A priority is finalizing the work of the Assessment and Competency Development Centre in identifying the competency gaps of existing operators and technicians and addressing them through proper solutions.\u0000 ATA is working now to maximize its intake capacity and deliver 600 graduates per year as well as getting the program accredited to the diploma level.","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":"85922082","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
京公网安备 11010802042870号
京ICP备2023020795号-1
扫码关注我们
求助内容：
应助结果提醒方式：