Day 2 Tue, November 01, 2022最新文献

{"title":"Time-Lapse Pulsed Neutron Logging Helps Maximize Recoveries from Mature Field - Case Study from Mangala Field of Rajasthan, India","authors":"Alok Kumar, Shraddha Sigtia, Joyjit Das, R. Guha, A. Ahmed, Vivek Shankar, Suresh Kumar, Nishi Chauhan, Ravinder Kumar, Sandeep Ramakrishna","doi":"10.2118/211347-ms","DOIUrl":"https://doi.org/10.2118/211347-ms","url":null,"abstract":"\u0000 Mangala Oilfield of Rajasthan has produced over 36% of STOIIP and has been subjected to several innovative and new era technologies since it started producing in August’ 2009. Initially, field was under Water flood phase till April’2015 and then full field Polymer flood phase started to maximize recovery. Mangala field with medium-gravity viscous crude oil & formation water salinity of approximately 8000ppm has an excellent reservoir property of high porosity (24 to 26%), high permeability (200md- 20D) and very low irreducible saturation i.e., less than 5%. Thus, C/O logging in this field has been a very good choice to estimate the remaining oil saturation (ROS) and understand the sweep of oil due to injection which in turn has helped in maximizing recoveries from the field.\u0000 Time-lapse PNL were run in several wells to monitor the efficacy of the water flood/polymer flood phase on oil recovery. The objective was two-fold; to estimate the change in saturation over time and to identify by-passed or marginally swept intervals. The process begins with recording the initial saturation in the wells before any production has occurred. Then time-lapse data are recorded to monitor the change in saturations. Secondly, saturation estimation from PNL data were used to plan the next course of action- workover operations, changing completion zones, abandoning certain zones or wells, and infill drillings. PNL data in combination with other reservoir surveillance techniques (MPLT) has proved to be a vital surveillance tool to maximize the recovery from this field.\u0000 In this paper, we present the effectiveness of PNL tool specially RMT-I with production data over a period of 3 years (post Aug 2019). However, the results also include integration of other PNL dataset (RST & Raptor) acquired for reservoir surveillance activity and the challenges involved in interpreting the result of different PNL tool over time.\u0000 In absence of RMT 3D tool, PNL is acquired as 1 Sigma up/down pass and 3 CO up passes at 1fpm-3fpm to address the uncertainty related to gas presence on C/O interpretation. Sigma measurement helped in identifying gas below packer or in the annulus behind pipe and helped in addressing the uncertainty related to gas presence on C/O interpretation. Secondly, RMT was planned in infill well post drill to determine the uncertainty between OH and Cased hole Oil saturation. The results agreed with production data and uncertainty in oil saturation estimation was minimized to 10-15% approximately. Several cases will be discussed in the paper to demonstrate the use of PNL logs for reservoir management.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"59 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115688985","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}

{"title":"Enhanced Single Trip Upper Completions for ERD Applications","authors":"Shardul Parihar, Zhihua Wang, John Andrew Wills, Jane Mason","doi":"10.2118/211557-ms","DOIUrl":"https://doi.org/10.2118/211557-ms","url":null,"abstract":"\u0000 An Abu Dhabi offshore field development plan comprises of ERD wells requiring intermediate / production casing depths of up to 23,000 ft with horizontal sail sections of approximately 10,000 ft of length. The original completion design involved drill pipe deployed intermediate completions, followed by a separate upper completion run with anchor latched seals. Over time, operational practices enabled the use of single-trip completions with tubing mounted packers, saving 2 – 3 rig days per well, but introduced some challenges. The objective was to maximize the usage of single-trip completions while continuing to leverage the advantages of an intermediate completion. Additionally, deployment enhancers such as lubricated fluid, low drag centralizers, and / or upsized tubing were included in the design to extend deployments deeper.\u0000 A comprehensive application review was conducted covering the system technical limits during installation and well life cycle operations. Detailed testing and modelling were carried out to understand the impact of deployment enhancers. This paper will provide insight as to the detailed drivers and design of the lubricated fluid and low drag centralizers. Additionally, the strategy for well trials and their successful results will be covered.\u0000 Several enhanced single-trip completion systems were successfully installed, confirming the efficiency gain of 2 – 3 rig days per well in high angle, deep casing ERD wells. The fluid lubrication provided 30 – 50% cased hole friction factor reduction. Additional long term well life cycle efficiencies were achieved, such as OPEX savings during future workover operations resulting from the anchor-latch feature and maintaining the same ID from the production packer down to the liner for future lower completion retrofit without requiring the production packer to be retrieved.\u0000 While single-trip upper completion systems have been used in the past, achieving the two-trip completion system advantages with a single-trip system was not possible before. Additionally, deploying the enhanced system coupled with deployment enhancers has allowed the completion of high angle and deep\u0000 casing ERD wells. Expectations are to extend application of this completion design to even deeper casing depths.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"6 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116981097","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}

{"title":"Enhanced Operational Integrity Management Via Digital Twin","authors":"S. Matthews, Ross Sutherland, Gareth McIntyre","doi":"10.2118/210998-ms","DOIUrl":"https://doi.org/10.2118/210998-ms","url":null,"abstract":"\u0000 During the early stages of the Covid pandemic, the oil and gas industry was faced with significant challenges in executing inspections for ageing offshore oil and gas infrastructure together with the management of various operational integrity threats. These challenges were addressed through the collaborative development of remote, digital techniques to minimise inspector time offshore and maximise efficiency.\u0000 This initially involved a review and challenge of our existing operational integrity management lifecycle, comprising systems data, risk-based strategy development, inspection planning, inspection execution, data management, anomaly management (including fabric maintenance and engineering repairs) and close-out. Working with our partner, GDi, we sought to drive a step change into digital integrity management, combined with streamlined workflows, activities, and administrative tasks.\u0000 The pilot development involved comprehensive laser scanning of a floating production storage and offloading (FPSO) facility to generate a dimensionally accurate digital twin, overlayed with 360° HD photogrammetry to provide a thorough baseline for subsequent general visual inspections of pressure equipment, piping systems and structural elements. General visual inspections can now be executed remotely, without the requirement for an offshore inspector. The digital twin environment also supported transformation of inspector-led activities, through optimisation of processes, digital inspection workflows via tablets and seamless integration with the integrity management platform. The pilot development also involved enhancing the anomaly risk management process, including management of mitigations (such as temporary repairs) and actions required to resolve and close anomalies. For the anomaly actions, the digital twin environment enables the accurate estimation of fabric maintenance scopes and dimensionally accurate repairs for corrective work orders. The system also facilitates a unique overview of cumulative risk via the plotting of anomalies in the digital twin space.\u0000 The digitally enhanced operational integrity management system has substantially reduced direct costs and personnel safety risks, enabled substantial improvements in productivity (up to 200% for inspections), and improved the quality of integrity management outcomes.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"26 5","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"120990390","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}

{"title":"Block-61 Rigless Method for Efficient Permanent Abandonment","authors":"Sultan Al Abri, Aala Abbas, M. Jaboob, Muna Al Abri, M. Najwani, S. Al Harrasi, K. Al Fadhli, T. Al Shidhani, A. Al Darai","doi":"10.2118/211160-ms","DOIUrl":"https://doi.org/10.2118/211160-ms","url":null,"abstract":"\u0000 Well Abandonment is an important stage in the life of any well and in the field development plan in general. Tight regulatory requirements along with high cost made it apparent to search for more innovative methods to design and execute well abandonments more efficiently.\u0000 Conventionally, well abandonment operations are performed by cementing the wellbore utilizing a drilling rig and its facilities, which is the main driver for the relatively high P&A cost. Here is where the method/initiative of \"Rigless abandonment\" came into play. This technique replaces the use of drilling rig with other intervention conveyance packages, resulting in a more efficient and cheaper plug and abandonment while satisfying all the regulatory isolation requirements.\u0000 For a non-standard abandonment operation, the rigless abandonment initiative was a great success. All the abandonment objectives have been met and required barriers have been established while spending 73% of the planned cost only. Despite the challenges faced during the operation, the well abandonment only took 1 day longer than planned. In addition, many lessons learned have been captured to avoid recurrence in the upcoming similar jobs.\u0000 In the year of 2019, a well in the northern part of bp's block 61 concession was deemed for abandonment due to poor reservoir performance. An opportunity was fore sought by the intervention team to design and execute the required abandonment in a \"rigless\" style. The planned process considered the use of coiled tubing unit to kill the well and place cement across the targeted Amin formation. Subsequently, utilizing the wireline service to place a plug across the packer before perforating above it. This step was to create a pathway for the cement to communicate between the A-Annulus and the tubing in the wellbore. Then, using the cement unit, the cement was reverse circulate down the annulus and up the tubing. To ensure the placement of the cement, a slickline drift run was conducted after the cement has cured, which indicated TOC at 480 m. Finally, the X-tree was removed, and the tubing and wellhead was cut at surface before performing a top-fill job to cement the remaining void up to surface.\u0000 The implementation of this abandonment operation also adhered to strict safety standards. The rigid bp safety process guidelines ensured that all challenges and optimization opportunities were fulfilled in a safe manner.\u0000 The purpose of this paper is to detail how the team pushed the technical envelope to introduce this methodology and share the journey of implementing a cheaper and safer well abandonment alternative.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125901139","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}

{"title":"A Fit-For-Purpose ESP Technical Solution Enables 17% Production Increase in Complex Reservoirs in Mature Fields in Ecuador","authors":"F. Leon, J. Pancho, Ernan Franco, Diego Balseca, Fernando Ruales, María Elena Quinzo, Mauricio Perez, J. Villalobos","doi":"10.2118/211331-ms","DOIUrl":"https://doi.org/10.2118/211331-ms","url":null,"abstract":"\u0000 A fit-for-purpose electrical submersible pump (ESP) technical solution, based on a combination of pump types and an innovative extended gas-handling device resulted a production increase of 17% in four mature fields in Ecuador. The extended gas-handling device enabled a superior performance of ESP systems to decrease downhole parameter fluctuations normally observed in challenging production conditions to improve oil production.\u0000 Historically, ESP operations in mature fields in Ecuador have posed extremely demanding conditions, where reservoir depletion generates lower static and flowing pressures that are typically associated with an increment in free-gas content in the produced fluid. Low flow rates, high lifting requirements, and high gas content degrade ESP performance and reliability while complying with field economics.\u0000 This innovative ESP technical approach improves fluid hydraulics through the pump by combining a newly developed extended gas-handling device with proper selection of pump stage models to avoid production losses due to gas blockage, leading to an increase of pressure drawdowns and the maximization of flow rates. Additionally, when the reservoir has had a fracturing job to improve its productivity, the ESP selection process becomes even more challenging. Therefore, this ESP configuration incorporates a robust technology to face abrasive conditions, and flow rates are thoroughly controlled during the well's initial production phase to mitigate excessive migration of proppant into the pump. The technical solution developed has helped to increase production and improve the equipment reliability. On the 47 wells where this technology was successfully adopted, a 17% increase in oil production was observed and was attributed to the system's capacity to maximize reservoir drawdowns, with intake pressures as low as to 150 psi, while maintaining stead operation in gassy conditions. The enhanced equipment performance obtained with this technology contributed to a reduction in the number of ESP failures having as root cause low productivity, which decreased from 34 in 2019–2020 to 16 in 2021–2022 with zero ESP-related failures recorded among the 47 wells where this technology was installed.\u0000 This innovative ESP configuration has emerged as a pioneering solution in the region to fulfill challenging production conditions in mature fields where a cost-effective solution is required. Furthermore, it opens a new spectrum to maximize oil production in mature fields by expanding the currently understood technical boundaries for ESP operation in low-flow gassy applications.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"120 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123449914","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}

{"title":"A Holistic Approach to the Development of Digital Twin Advisor for Upstream Production Process","authors":"M. Z. Mohd Sahak, Maung Maung Myo Thant, A. Tumian, Z. Harun, Eugene Castillano, S. B. Chee, Kathryn Tan","doi":"10.2118/210979-ms","DOIUrl":"https://doi.org/10.2118/210979-ms","url":null,"abstract":"\u0000 From upstream production process/operation perspectives, adoption of digital twin linked with real-time data for operational monitoring and advisory can assist in early determination of abnormalities that can result in potential failure events, based on deviation from the operating setpoints and limits. In addition, prediction capability of the digital twin model can assist in prevention of unplanned production deferment and proper maintenance planning. The digital twin model can also recommend optimum operating points based on changes in the system as operational guidance to further improve and optimize the system performance. This paper outlines the holistic approach taken for the development of digital twin-based advisory system for upstream process monitoring and optimization.\u0000 Based on a case study, a step-by-step approach for the development of a digital twin model for fuel gas system is being described. This technology combines various aspect of process and operation models. The Integrated Operating Limit Model acts as the first layer of digital twin model, which provides the operators with a quick assessment based on the visualization or representation of the real time operating points versus the operating set points and limits defined in the system. Process simulation model predicts other operating parameters not covered by the existing instrumentations, serving as virtual analysers, providing near real-time equipment and unit performance. Data driven model can be used for prediction, optimization and anomaly detection, and based on the prediction model development, comparison between linear regression (LR) versus decision forest-based model showed LR to be more reliable approach based on the validation against the actual operation data especially during upset condition (R2 of 0.9 vs 0.27). A graphical user interface was also developed to translate and summarize the model outputs into a clear visualization to be used by the operation team as advisory and surveillance tool. Combination of these models’ outputs would allow operator to essentially screen for potential process upset and apply further optimization based on the recommendation provided.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"279 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116039081","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}

{"title":"Hydraulic Fracturing QA QC Indispensable to Delivering Both a Successful and Economic Fracture Program","authors":"Hussein Al Salmi, A. Al Shueili, M. Jaboob, M. Al Qassabi","doi":"10.2118/211337-ms","DOIUrl":"https://doi.org/10.2118/211337-ms","url":null,"abstract":"\u0000 It is well known that close quality assurance and quality control (QA/QC) are of vital importance for the successful placement of any hydraulic fracturing treatment. Many complex pieces of equipment and specialized personnel are involved in the fracturing process, and the following of strict QA/QC standards is mandatory to make these operations successful, efficient and safe. BP Oman is using massive hydraulic fracturing treatments to exploit the challenging tight-gas Barik Formation in the Khazzan and Ghazeer Fields. Each treatment is designed to place 1 million pounds of proppant into this tight, high pressure high temperature reservoir, leaving no space for error.\u0000 Implementing QA/QC and logistic supply measures begins with the mobilization procedures: chemicals checklist/verification and mixing on the base, timely equipment maintenance, bulk plant proppant delivery to ensure a swift and smooth 24 hour operation. Water delivery management loading quality check, logistics, site acceptance and minimum quality checks are another important procedure related to this preparation. Each fracturing stage requires at least 14,000 bbl of fresh water to be available and quality checked on the site before the start of the fracturing treatments. Intensive QA/QC measures continue through the day of the fracturing treatment itself to ensure the equipment is in full working condition. Assurance that all of the supply systems are properly calibrated, all chemicals loaded and levels physically measured. During the fracture treatment itself all parameters are repeatedly measured and visualized in real time. Fluid viscosity is assessed on the fly and data verified with an HPHT viscosimeter also present on the wellsite. After the treatment, all remaining chemicals are measured once again and carefully assessed against the expected inventory values and material balanced.\u0000 Implementing extensive QA/QC procedures enabled efficient mobilization between wells with mobilization time as low as 6 days despite the complex equipment and material needs for these massive fracturing treatments. Planned logistics and consistent quality checks before, during and after the treatment enabled BP Oman to successfully place more than 100 hydraulic fracturing stages with the amount of proppant exceeding 1 million pounds per stage. The bar has raised even higher with successful placement of 2 million pounds of proppant, the largest single stage hydraulic fracturing treatment in the Eastern hemisphere at the time of execution.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"29 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114378841","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}

{"title":"New Exploration Plays in Sohar Basin UAE","authors":"G. Williams, Callum Thurley, E. Cox, Donald Stewart, Mark Sarssam, Masoud Al Hamadi","doi":"10.2118/211604-ms","DOIUrl":"https://doi.org/10.2118/211604-ms","url":null,"abstract":"\u0000 The Sohar Basin, located offshore the East Coast of the Arabian Peninsula, is a long-ignored area adjacent to the super basins of the Arabian Plate. Three dry wells were drilled in the northern Sohar Basin between 1969 and 1980 on structural anomalies. In 2001, a 3D survey was acquired over the UAE portion of the basin in the belief that the Arabian Platform Carbonates extended from the Rub al Khali Basin, beneath the Semail Ophiolite to the east. This study depicts how this legacy 3D dataset has been re-evaluated to define new prospectivity.\u0000 A tectonic history defined by a sequence stratigraphic and structural interpretation of the 3D data as well as a basin modeling exercise has revealed a previously unexamined petroleum system. These include Miocene to Eocene-aged turbidite channel and fan complexes representing potential reservoir units. In the deeper section, high reflectivity layers within ‘mini-basins’, have seismic characteristics consistent with organic rich source rock layers. Basin modelling indicates that these layers would be mature for hydrocarbon generation. Shallow bright spots provide evidence for hydrocarbon migration along deep-seated faults.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"144 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"114477350","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}

{"title":"Automatic Drilling Operations Coding and Classification Utilizing Text Recognition Machine Learning Algorithms","authors":"M. Amer, Bader M Otaibi, Amr I Othman","doi":"10.2118/211851-ms","DOIUrl":"https://doi.org/10.2118/211851-ms","url":null,"abstract":"\u0000 Digital transformation is becoming a major goal for oil and gas (O&G) companies, and one major component of digital transformation initiatives is utilizing artificial intelligence (AI) and machine learning (ML) algorithms/techniques to automate critical business processes for the sake of consistency and objectivity. Drilling operations classification and coding is always challenging due to the subjectivity of end users; however, using machine learning and big data to automate operations classification based on natural language operations descriptions provided by drilling personnel can ensure objective and consistent classification.\u0000 In this paper, a new approach is introduced for using ML algorithms to classify drilling operations based on the operation description provided by rig personnel in their morning reports, with time broken down using natural language.\u0000 The new ML predictive model learns from historical data how to define the proper coding of drilling operations based on operation description to minimize human interaction with the coding system for drilling operations. The approach utilizes a set of prediction models to predict the proper code combinations that classify the activity carried out on the rig floor. Each model of these proposed models will feed its prediction into the next model to define the next level of code predictions. The model was trained using around 800,000 records to define the coding patterns based on operation remarks and then predicted a multi-level operational coding for any given operational remarks.\u0000 The model has been tested and validated with around 800,000 records from datasets from multiple years, and showed significate results when compared to recent reports and subject matter expert evaluations showing a very good level of consistency and level of accuracy of more than 80%.\u0000 The result of this work is an ML classification model that can reduce daily morning report data entry by 40% and improve the operational classification quality and consistency significantly. This approach also improves internal processes such as services invoicing verification, bit selection and end-of-well reporting.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"5 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"129502411","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}

{"title":"An Innovative Method of Water Management by Desalinating the Produced Water Using Thermal Renewable Energy","authors":"Sharifa Mohammed Al Ruheili, F. Tiefenbacher, Khansaa Hamed Al Mahrami, Nazir Othman Shahin, Omar Salim Al Jaaidi","doi":"10.2118/211175-ms","DOIUrl":"https://doi.org/10.2118/211175-ms","url":null,"abstract":"\u0000 Produced water, which in many cases shows a high degree of salinity, is currently managed using water disposal wells and evaporation ponds. Both methods are conventional and have negative environmental impacts. ARA is adopting a unique and innovative method to manage high salinity produced water in an environmentally sustainable way by extracting potable water from produced water and reducing discharge water volume by at least 50%. For desalination of the produced water an innovative combination of forward and direct osmosis technology is used. This process is driven mostly by thermal energy which is provided to 100% solar thermal collectors.\u0000 The structure of the plant is as follows: A solar thermal power plant consisting of 2 desert- and oilfield-proof solar thermal collectors (\"HELIOtubes\") with thermal energy storage (TES) using pressurized water for nighttime operations (24/7). The solar thermal plant powers an advanced forward osmosis desalination (FO) and brine concentration Direct Osmosis (DO) unit with pre-treatment unit to cope with the challenging produced water.\u0000 This project is in the pipeline for implementation. The engineering and the planning design were successfully completed. Two main results are expected from this project, which is: (i) low-cost and low-maintenance thermal power and (ii) desalinated water from the produced water meeting the regulatory specifications.\u0000 It is a state-of-the-art system integration engineering based on the simulation of the innovative desert-proof solar thermal plant including TES using 10-year historical satellite-based irradiation data to show optimal use of renewable energy. Lab studies show how low energy consumption pre-treatment of the challenging produced water with its difficult chemical composition can be achieved, allowing membrane-based forward osmosis to be applied even at a salinity level that is 3-times higher than seawater. That leads to high energy efficiency for desalination also at nighttime based on thermal power from cost-effective TES instead of expensive batteries. This system could be considered a game-changer in the oil and gas industry because it introduces a new water management methodology.","PeriodicalId":249690,"journal":{"name":"Day 2 Tue, November 01, 2022","volume":"91 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2022-10-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123616871","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}