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The United Arab Emirates’ (UAE) chief energy regulator has announced that the country holds a substantial volume of newly discovered unconventional resources as it approved a 5-year spending plan for the Abu Dhabi National Oil Company (ADNOC). The Supreme Petroleum Council, which also serves as ADNOC’s board of directors, placed the estimated reserves of unconventional oil within the Emirate of Abu Dhabi at 22 billion bbl, according to a government news release on 22 November. The figure would place the UAE’s tight reservoir potential on par with that of some of the biggest plays in North America. The government also said that an additional 2 billion bbl of reserves was also recently discovered, raising the UAE’s total conventional reserve estimate to 107 billion bbl. Both the conventional and unconventional estimates were independently verified by Houston-based reserves specialist Ryder Scott.
The Abu Dhabi National Oil Company (ADNOC) announced that it has completed the first phase of its large-scale multiyear predictive maintenance project, which aims to maximize asset efficiency and integrity across its upstream and downstream operations. ADNOC says its predictive maintenance platform uses artificial intelligence (AI) technologies such as machine learning and digital twins, ADNOC’s to help predict equipment stoppages, reduce unplanned equipment maintenance and downtime, and increase reliability and safety. The company said it expects use of the platform to result in maintenance savings of up to 20%. The predictive maintenance project, which was announced in November 2019, is being implemented over four phases. ADNOC’s predictive maintenance project is part of the company’s digital acceleration program, which focuses on embedding advanced digital technologies across the company’s operations.
ADNOC LNG signed a supply agreement for up to 6 years with Vitol for the sale of 1.8 mtpa of post-2022 LNG volumes, and a 2-year supply agreement with Total for 0.75 mtpa of 2021 and 2022 LNG volumes. The agreements continue ADNOC’s transition to a multi-customer strategy that began in 2019, and follow its investment partnership with Vitol in global storage terminal owner and operator VTTI. Since then, the company shifted from supplying 90% of its LNG to Japan to supplying 90% of LNG to clients in more than eight countries from across southern and southeast Asia. The agreement is also in line with its 2030 gas strategy to deliver value for UAE and meet global demand, which is expected to grow by up to 5% annually over the next 20 years. ADNOC LNG, owned by ADNOC (70%), Mitsui & Co (15%), BP (10%), and Total (5%), produces about 6 mtpa of LNG from its Das Island facilities off the coast of Abu Dhabi.
The Abu Dhabi National Oil Company (ADNOC) completed the first phase of its large-scale multiyear predictive maintenance project to improve asset efficiency and integrity across its upstream and downstream operations. Announced in November 2019, the project is being implemented over four phases as part of the company’s digital acceleration program to embed advanced digital technologies across its operations. Phase 1 covers the modeling and monitoring of 160 turbines, motors, centrifugal pumps, and compressors across six ADNOC Group companies. All phases of the project are expected to be completed by 2022 and will enable monitoring of up to 2,500 critical machines. Using artificial intelligence (AI) technologies including machine learning and digital twins, the company’s predictive maintenance platform helps with equipment stoppages, reduces unplanned equipment maintenance and downtime, increases reliability and safety, and is expected to deliver maintenance savings up to 20%.
UAE Has Become World's Newest Producer Of Unconventional Gas The United Arab Emirates (UAE) has become the latest country to prove that the unconventional oil and gas sector is becoming firmly an international one. This comes as the Abu Dhabi National Oil Company (ADNOC) and its French partner Total announced today the first delivery of unconventional gas from a jointly operated onshore field in the UAE. ADNOC said the gas delivery represents a major advance toward the company’s goal of producing 1 Bcf/D by 2030, enough to meet all the UAE’s domestic natural-gas demand. The shale-gas field where ADNOC and Total hope to accomplish this is known as the Ruwais Diyab Unconventional Gas Concession and is located almost 125 miles from Abu Dhabi. The companies said they used a fast-track approach to expedite the midstream components needed to move the gas from the greenfield to existing processing facilities.
Vasquez Bautista, Ramiro Oswaldo (Schlumberge) | Ioan, Tiberiu (Schlumberge) | Benny, Praveen (Schlumberge) | Alwahedi, Khalid (ADNOC) | Hevia, Gonzalo (ADNOC) | Menedez Blanco, Miguel Angel (ADNOC) | Cesetti, Maurizio (ADNOC)
Abu Dhabi National Oil Company (ADNOC) offshore and Schlumberger jointly initiated a project to drill the longest 12¼-in section ever drilled in United Arabs Emirates (UAE) as part of the integrated drilling service for an extended-reach project. The plan involved drilling 14,400 ft in an extended-reach drilling (ERD) well in the field. The objective was to reach section TD in one run, drilling from 5,194-ft MD and reaching TD at 19,494 ft MD.
In the well in study, Well 29, the trajectory crossed different formations—including limestones, shales, and dolomites—and built inclination from 30° to 78° to achieve an optimal step-out for the following sections to reach the boundaries of the reservoir at 27,000 ft. Different formation challenges throughout the section required a step change in engineering to complete the objective successfully. ADNOC needed a robust steerable system selection with metal-to-metal sealing that would be exposed to severe downhole conditions, a new bit technology design, anti-collision analysis to help reduce additional gyroscopic operations, and optimized drilling parameters with an enhanced drillstring design.
The section was planned to drill in 17.7 days. The total section was finished 10 days ahead of planned AFE, setting the record for the longest 12¼-in section ever drilled in ADNOC and UAE of 14,400 ft, which was 58% longer lateral than field average. Through increased cutting efficiency and superior impact resistance, the new bit design with ridged diamond elements drilled the fastest 12¼-in section on the field in 0.91 d/1,000 ft. Good hole conditions facilitated successfully running and cementing the longest 9�?-in casing, meeting ADNOC well integrity barrier requirements.
The 12¼-in section had the fastest IADC-recorded ROP in the field, with an on-bottom ROP of 105 ft/h, which was 110% faster than the field average.
The Geomagnetic Reference Service correction was implemented for the first time and was allowed to drill in proximity with a high anti-collision risk well, eliminating a gyro trip in the middle of the run.
Downhole drilling parameters analysis from the drilling mechanics module was crucial for understanding downhole energy transmission and implementation of efficient drilling strategy and reducing shocks and vibrations.
The drillstring was redesigned, replacing the traditional 5-in × 5⅞-in drillpipe and enabling a stiffer BHA, which helped maximize the bit performance.
Singh, Maniesh (ADNOC osnhore) | Al Arfi, Saif (ADNOC osnhore) | Boyd, Douglas (ADNOC) | Gerges, Nader (ADNOC) | Fares, Wael (Halliburton) | Clegg, Nigel (Halliburton) | Aki, Ahmet (Halliburton) | Diab, Emad (Halliburton) | Pandey, Vikram (ADNOC onshore) | Mansoori, Maisoon M. Al (ADNOC onshore) | Seddik, Ibrahim A. (ADNOC onshore) | Reddy, Rathnakar (ADNOC onshore)
ADNOC's limestone reservoirs suffer from the phenomena of injection water traveling preferentially at the top of the reservoir placing injection water above oil held there by capillary forces. Horizontal wells placed below areas of water override, cause the water above to slump unpredictably, increasing water cut and eventually killing the horizontal. Ultra Deep Directional Electromagnetic (EM) Logging While Drilling (LWD) tools provide the measurements to identify and map these water zones, improving reservoir management and design optimal well placement.
1D & 2D EM inversion modeling was conducted on two of ADNOC's largest oil producing reservoirs to evaluate the ability of an Ultra Deep Directional EM LWD Resistivity tool to identify water slumping in the presence of formation bed resistivity contrasts and predict depths of reliable detection (DOD) under various well trajectory scenarios. The inversion was run using depth of inversions up to 150 ft, the maximum expected vertical distance of tool to injection water. Modeling provided an optimized tool configuration (frequency, transmitter-receiver spacing's) to meet objectives. The inversion results further provided guidance for Geosteering, Geomapping and Geostopping decisions.
The inversion results in these reservoirs indicated that the Ultra Deep resistivity tool has a DOD of 50-150 ft to pick reservoir tops and water slumping or non-uniform waterfront boundaries. The real-time inversion will optimize landing and drilling long horizontal section to increase net pay for production and even through sub-seismic faults, measuring changes in the reservoir fluid distribution, reduce drilling risk and exceed well production life. This information will aid in updating static model with water flood areas, reservoir tops, faults and structure, designing better infill well spacing and trajectories within bypass oil regions, designing proactive and not reactive smart well completions to delay or reduce water production and ultimately extended plateau and improve ultimate recovery factor. Furthermore, it will aid resistivity mapping of underlying or overlying reservoirs for future development plans.
The encouraging results of this study confirmed to move forward with a field trial in these challenging reservoirs for better reservoir and fluid characterization and its management.
This paper explains how advanced digitalization concepts were employed in the development and construction of the Taweelah Gas Compression Plant in the United Arab Emirates (UAE). The plant began operation in late 2018 and is one of the largest and most modern compression facilities in the world. It is owned and operated by the Abu Dhabi National Oil Company (ADNOC) and comprises three compression trains, each with a processing capacity of 225 million standard cubic feet per day (mmscfd). Two operate at any one time, with the third on standby, giving the plant 450 mmscfd of total production throughput.
Using the Taweelah Gas Compression Plant as an example, the paper describes how onshore oil and gas compression stations can be built efficiently and economically by leveraging advanced digital technologies, such as Digital Twins. Other concepts/strategies that the paper will discuss which can help accelerate project schedules and reduce costs include:
Sophisticated hydraulic modeling software; Large power blocks to reduce the number of compression trains; Sole-source provisioning of compression drive trains; ‘Plug and play’ equipment packages that required minimal onsite commissioning; Remote diagnostics and analytics for condition monitoring and condition-based maintenance to ensure maximum uptime and availability;
Sophisticated hydraulic modeling software;
Large power blocks to reduce the number of compression trains;
Sole-source provisioning of compression drive trains;
‘Plug and play’ equipment packages that required minimal onsite commissioning;
Remote diagnostics and analytics for condition monitoring and condition-based maintenance to ensure maximum uptime and availability;
Using the combination of the above concepts, along with extensive collaboration/co-creation between Siemens Energy and ADNOC, the Taweelah plant was able to achieve first gas just 16 months after front-end engineering design (FEED).
ADNOC's business strategy has dynamically changed in response to the rapidly changing and increasingly complex business issues. One of the critical components of ADNOC Gas Processing's maintenance strategy is to have a clear strategy for outsourcing maintenance work. The Maintenance Outsourcing Strategy precisely fulfils this requirement. It serves as the basis for all future initiatives to reduce maintenance costs, increase productivity, improve the quality of service, and generate higher returns for shareholders without jeopardizing safety, integrity and reliability.
ADNOC Gas Processing shall use a phased decision model to take more informed outsourcing decisions, rather than using a defensive strategy to try and fix performance issues. The outsourcing selection model provides the sequence of analyses for the model. During the first phase, the strategic evaluation consists of a core competency analysis to determine if a component is a Production Critical Equipment (PCE) maintenance activity, and activity significance analysis that takes other important strategic factors like OEM requirements into consideration. In the second phase, the economic analysis looks at the economic feasibility of the outsourcing strategy using the Cost-Benefit Analysis (CBA) tool. In the third phase, the risk analysis is carried out using the risk evaluation tool to determine if the activity is of high or low risk. And in the last phase, the final decision is arrived at by combining the outputs from the strategic evaluation, economic analysis and commercial risk analysis, and formulating the best decision for the ADNOC Gas Processing. Results, Observations, Conclusions: The main goals of implementing this strategy are to reduce maintenance costs, increase productivity, improve the quality of service, and generate higher returns for shareholders without jeopardizing integrity and reliability. The primary goals of outsourcing are Improve Business Focus, Reduce Cost, Control Risk, Optimize Planning and Scheduling, and Improve Maintenance Performance.
The ever-increasing need for resilient strategies demands the supreme understanding of business uncertainties and the execution risks. For the National Oil Companies like, ADNOC, the annual reservoir performance review (ARPR) is a process of paramount importance, as it provides a holistic overview of the reservoir performance status for each ADNOC field on yearly basis. It unfolds the subsurface performance issues, uncertainties and risks, and steers the decisions of Business Plan sanctions.
The ARPR execution demands a tremendous amount of time and effort to assimilate information and create a consolidated decision support package. In the absence of an automated process, the creation of insightful analytics, proper tracking of actions and maturation of value-driven opportunities become unmanageable. Thus, the automation of the process asserted to demonstrate a significant reduction of the data preparation time, increased multidisciplinary collaboration, centralized data archiving and integrated dashboard generation.
A multidisciplinary team of ADNOC's subject matter experts joined forces to develop a fit-for-purpose automated solution (
The solution enables assigning tasks to users at various supervisory and coordinating levels through an automated governance system. It provides means to monitor the progress of the work, approve the content of Elements and Sections, and review the concatenated ARPR document for final approval. All the integrated analyses get stored into the corporate repositories for any future utilization in data mining and advance analytics workflows.
The automated solution (