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Collaborating Authors
Transforming Production Phase WIMS to a Game Changer Smart Well Integrity Monitoring System with Real Time Automated Engineering Analytics
Jasem, Mohammed (ADNOC Sour Gas) | Fabian, Oka (ADNOC Sour Gas) | Dawson, Graeme (ADNOC Sour Gas) | Silari, Madhukar (ADNOC Sour Gas) | Al Junaibi, Bader (ADNOC Sour Gas) | Challagundla, Srinvisa (ADNOC Sour Gas) | Noble, Steven (ADNOC Sour Gas) | Al Sawadi, Obadah (Halliburton) | Rodriguez, Jose (Halliburton) | Mylnikov, Pavel (Halliburton) | Ge, Haoyou (Halliburton)
Abstract First implementation of a new well integrity management solution with integrated and automated workflows, the Well Integrity Management solution (WIMS) that helps company to minimize risks and production loss by the real-time monitoring of the operating limits of sour gas wells. Leveraging digital twin technology, the new software enables engineers to rapidly identify high-risk wells, take corrective actions faster, and mitigate issues to maximize well availability. Previously, the process of monitoring well integrity was based on the multiple software applications which is time-consuming. To address the challenge, we developed a WIMS coupled with the well engineering analysis approach. The system achieves the following: Representative and accurate well barrier equipment inventory for the entire asset. Safely operate critical HPHT wells to their maximum potential, Eliminate critical and costly barrier failures while minimizing production interruption through automated workflows and alert triggers, Free SMEs to perform critical well integrity management tasks, including technical reviews of sensitivity analysis that determine more accurate MAASP/MAWOP values, Track corporate KPIs and report regulatory requirements effectively. WIMS integrates source system for the well engineering applications. A first-of-its kind, WIMS uses Real Time engineering analytics and artificial intelligence to run as a Digital Twin for well's Operating Limits and diagnoses potential failures. It also measures, reports and displays most realistic well integrity status for the wells, based on company well integrity standards, processes and best practices. This paper details how we were able to successfully address these challenges which encouraged us mutually to work towards further integration with engineering tools and more automation of WIMS processes. Important Note: All well data, engineering analysis, operating limits and well information etc., displayed or referred to in this publication, are not necessarily actual and only used for illustration purposes.
Flow Assurance in High-Pressure Water Injection Flowlines using GRE Composite Lined API 5CT Threaded and Coupled Tubing
Abdel-Aleem, Mohamed Ibrahim (Petroleum Company Shell Egypt J/V) | Abdel-Mottleb, Mohamed Kamal (Petroleum Company Shell Egypt J/V) | Mohamed, Mohamed Sobhy (Petroleum Company Shell Egypt J/V) | El-Dardiery, Mahmoud Mohamed (Petroleum Company Shell Egypt J/V) | El-Din, Reda Aly (Petroleum Company Shell Egypt J/V) | Radhakrishnan, Gokulnath (Maxtube Limited) | Youssef, Etman (Maxtube Limited) | Fernandes, Alwyn (Maxtube Limited) | Khouly, Amr Al (Maxtube Limited)
Abstract In a first ever case within Shell assets worldwide, Badr Petroleum Company (Bapetco) - a Shell Joint Venture Company in Egypt, has embarked on a project of replacing a 20 km Water Injection network, originally constructed with Welded API 5L carbon steel pipe, with fiberglass lined API 5CT Threaded and Coupled tubing. The original network is a conventional pipeline system of welded pipes transferring brine from 3 Water Source wells to 23 Water Injectors through the Egyptian Western Desert. The water is of a high salinity of 180,000 ppm saturated with dissolved oxygen up to 1,000 ppb before chemical treatment. After injecting oxygen scavenger the concentration of the dissolved oxygen is 100 ppb. As a result, Bapetco has been facing severe corrosion related failures in Water Injection flowlines. The 20 km surface pipeline network had to be totally replaced approximately once every two years. Many of the Water Source and Water Injection wells in this network were completed using GRE lined tubing for internal corrosion protection. However, corrosion by-products from the carbon steel flowline were a cause for concern given the risk of plugging the reservoir. Basic remedial solutions such as clamps, chemical inhibitions, patches etc. were carried out on the flowline. Nevertheless a more manageable approach was sought especially after reviewing the life cycle costs of maintaining the network and the impact of frequent drops in injection rates on the overall production from the field. Bapetco embarked on an ambitious plan to use API 5CT Threaded and Coupled Steel Tubing internally lined with fiberglass for corrosion protection to replace the bare Carbon Steel pipeline. Shell's confidence in GRE lining has been established over 20 years of using GRE lined tubing downhole in 11 countries. This endeavor also helps Bapetco utilize unused inventory of tubing instead of additional capex required for flowline replacement with API 5L pipes manufactured from more exotic steel. The integration of API 5CT specification threaded and coupled tubulars into Pipeline Engineering design, considering flow dynamics and make up compatibility with standard valves and fittings, is a huge challenge given the lack of applicable design codes, standards and Engineering common ground. Special components were engineered to provide a transition between GRE lined tubulars and plain end unlined fittings and flanges. Also, pressure testing, pigging and connection make-up procedures were reviewed and/or revised to accommodate the use of GRE lined API 5CT pipes in flowlines. This paper chronicles the history of the Water Flood project, the nature, reasons and consequences of the multiple corrosion failures and the failed corrosion mitigation strategies. Furthermore, the paper will shed light on the techno-commercial analysis and engineering that forms the basis for this mammoth effort.
- Water & Waste Management > Water Management > Lifecycle > Disposal/Injection (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Well Completion > Well Integrity > Subsurface corrosion (tubing, casing, completion equipment, conductor) (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
- Production and Well Operations > Production Chemistry, Metallurgy and Biology > Corrosion inhibition and management (including H2S and CO2) (1.00)
- (2 more...)
Abstract Oil companies increasingly rely on the use of computing tools to increase economic recovery from producing fields, whilst reducing cost and boosting output by improving staff efficiency. In addition to generating technical benefits, these computing tools facilitate and promote integration between disciplines. With their use, hydrocarbon asset development plans can be made technically and economically more robust, since a multitude of development options can be evaluated in a shorter timespan. Furthermore, a variety of subsurface scenarios can be simulated well in advance of executing any activity. Hence, the potential risks (drilling risks, production risks, etc.) can be comprehensively assessed, leading to improved planning and operations. This approach often results in optimal, fit for purpose facilities, at lower costs. It also improves contingency planning, thereby increasing safety and reducing the environmental impact of operations. It can be demonstrated that well planned and managed investments in Information Management and Technology ultimately increase profitability. Between 1994 and 1996, the Badr El Din Petroleum Company implemented an integrated system of computing applications and the supporting hardware and infrastructure. This paper discusses the implementation process with an emphasis on the petroleum engineering part of the portfolio, presents examples of specific application in field development and discusses associated business benefits. Key success factors and lessons learnt are highlighted and future plans outlined. Introduction The Badr El Din Petroleum Company (Bapetco), ranks amongst Egypt's 10 largest joint venture operators. Daily production averages some 25 000 STB of oil and condensate and some 300 MMSCF of gas. The company aims to continuously increase value of its operations on behalf of the shareholders, by pursuing the following targets:โincrease ultimate recovery and production rates; โreduce costs of developing hydrocarbon assets; โimprove staff competence and efficiency; โconduct a safe and environmentally friendly business. Management identified the use of new technology to be a key driver in the process to achieve the above targets. These tools would allow:โunproved characterization of reservoir architecture (petrophysical and reservoir modelling techniques); - improved quantification of dynamic processes (subsurface reservoir simulation and surface process simulation); โunproved access to, and drainage of; hydrocarbon resources (drilling/completion technology); โimproved staff productivity and competence (desktop PC productivity tools, computer network), as human resources are considered an essential asset. Therefore, in addition to promoting the introduction of new technology in areas such as drilling and completion design, it was decided to strongly focus on introduction of Information Management and Technology (IM&T) across the company. This has resulted in the implementation of a comprehensive portfolio of productivity tools and technical applications, supported by the appropriate hardware and infrastructure. Today, some 19 technical (RISC) workstations, mainly used for exploration and petroleum engineering technical applications, and some 270 PCs, have been installed. A company wide network has been installed, including links to remote field operations. As part of this ongoing effort, implementation of a comprehensive petroleum engineering software portfolio was initiated in 1994. P. 315^
Successful Implementation of a Digital Production Monitoring Solution Eliminating Data Entropy
Belaid, Faycal (Sonatrach Association) | Sami, Zahir (Sonatrach Association) | Larachiche, Mohamed Nassim (Sonatrach Association) | Hemmaz, Abdelghani (Sonatrach Association) | Kedia, Rachit (Halliburton) | Abdullayev, Azer (Halliburton) | Amarni, Mohamed (Halliburton) | Sadoun, Amar (Halliburton)
Abstract In conventional production management, a lot of production reporting is dependent on the analysis of a vast amount of data from different sources - this is the key to effectively analyze the behavior of the production systems and plan timely interventions. More often than not, as the E&P organizations go through the production lifecycle, it becomes increasingly difficult to keep this data in a structured format and a place where it can be easily accessed by the end users for their day-to-day workflows (Moustafa, et al., 2020). This paper talks about a digital initiative for Sonatrach to automate daily production reporting, provide efficient access to production data and deliver powerful analytical capabilities to end users through role-based information dashboards. The legacy approach to production reporting relied heavily on the Sonatrach staff manually gathering production data through Excel spreadsheets from the seventeen in-country joint ventures (JVs), which consumed significant staff productivity and carried a high potential for erroneous data entries. Moreover, the lack of a structured system of records to store JVs production data restricted the staff's ability to meaningfully collaborate with and contribute their expertise to the JVs. On the other hand, the huge pile up of these Excel spreadsheets created a data entropy and bottlenecked efficient production data management. The digital solution implemented to overcome these challenges involved 1 - Configuration of detailed production information dashboards that enabled all the organizational stakeholders to access actionable information, anytime and from anywhere, 2 - Automation of all the tasks related to manual data handling, 3 - Delivery of a central production data repository (CPDR), which stored all the relevant production data by integrating with JVs source systems and fed production dashboards with the quality data, 4 - Establishment of a technology platform to drive workflows and insight-driven analytics The implementation of this bespoke digital system enabled maximum utilization and faster adoption of the technology. The high degree of automation eliminated the time-consuming efforts and let Sonatrach's staff focus on high value tasks. In addition to that, it resulted in an improved collaboration between them & the JVs and a better utilization of Sonatrach's expertise. The detailed dashboards provided a better oversight of the operations and delivery of the business plans, and a unified database secured the opportunity for advanced analytics and better identification of production enhancements. The new solution, built on an open & scalable architecture, opened the pathways to accommodate additional workflows, business rules, dashboards and new data sources without costly workarounds associated with closed and proprietary systems. As a result, it has proved to be an important cogwheel in Sonatrach's digital transformation journey.
- Africa > Middle East > Algeria (1.00)
- Asia > Middle East > UAE > Abu Dhabi Emirate > Abu Dhabi (0.17)
Abstract In an attempt that is considered the first in well stimulation techniques by means of Hydraulic Fracture practice in GRE lined tubing, Badr Petroleum Company, BAPETCO (A SHELL Joint Venture in Egypt) has a successful experience to report. The company performed a hydraulic fracture operation through one of its water injection well installations completed with GRE (fiberglass) lining. The need for fiberglass tubular lining raised from the fact that the injected water in Neag-1 field is saturated with 1000 ppb of oxygen content and a range between 60,000 to 80,000 of salinity which led to an active corrosion cell within the downhole injection strings. The company has been using GRE fiberglass lining for their downhole tubing since 2013 for corrosion protection. However, whenever a frac job was required in a GRE lined string, the tubing had to be pulled out of hole, a frac string had to be run allowing for flowback through the temporary frac string and then the GRE lined string to be re-run again. This sequence of processes lead to a significant downtime and increased workover costs. The concerns about the hydraulic fracture jobs with a GRE lined string came from the fear that the proppants flowing back would erode away the internal GRE lining. There was no availability of any test reports on erosion from conditions mimicking frac jobs through GRE lined tubing that could duplicate the flow back conditions. In two of the wells already completed with GRE lined tubing since 2014, the operations required hydraulic fracture job to be carried out using proppants. The injection rates were high at 20 barrels per minute (28,800 bpd flow rate) for a period of 30 minutes. The proppant injection pressure was 4000 psi. The flow back (cleaning post frac) took 24 hours to complete. 90,000 lb of proppants was injected. At the completion of the fracture job operations in 2018, no returns of GRE or flare or corrosion barrier ring pieces were collected in the surface. The paper will share the intervention jobs that have been recently run through the tubing that corroborates with the fact that the GRE lining inside the tubing is intact. This paper demonstrates the preparatory steps taken by the company to carry out hydraulic fracture jobs through a fiberglass GRE lined string and the learnings from this operation. It also sets a new limit on the erosional resistance of GRE lined tubing. The paper will also highlight the gains of Bapetco utilizing GRE within their water injection wells for corrosion protection. The injection flowrate gains will also be shared in detail, as well as the economic gains of performing the frac job through an already RIH GRE lined string instead of using the conventional frac string operation procedures.