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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.
Reservoir model history matching is the solving process of a complex inverse equation mainly relating reservoir and well properties to observed data using a time and space discretized numerical model. A challenging task for engineers but a prerequisite to a vital tool to field development and business planning. This paper presents the calibration of a giant Middle East carbonate reservoir from scratch following a major field review. The objective of this integrated history match was to provide a reliable and sustainable representation of the reservoir in order to:
Predict performance, necessary strategies and expenditures for field development Reproduce the fluid distribution and the flow mechanism Represent the areas of the reservoir where there are no data Discover then solve or anticipate any operational issue
Predict performance, necessary strategies and expenditures for field development
Reproduce the fluid distribution and the flow mechanism
Represent the areas of the reservoir where there are no data
Discover then solve or anticipate any operational issue
It is a tedious work to calibrate coherently the static and dynamic models of a Giant field with complex geological heterogeneities, more than a thousand wells and forty-four years of history where multiple scenarios can coexist. This paper will present the workflow used to achieve a reliable and sustainable representation while narrowing down the number of solutions by using:
Theoretical and analytical calculations on paper to assess the foundation and physics behind the reservoir behavior Phenomenological models to understand the main drivers and reproduce the flow mechanism with a more flexible tool Regional geology and migration history to estimate untested parameters away from the oil pool especially inside the aquifer An iterative and innovative Static-Dynamic integrated process to generate a reservoir characterization honoring geology and performance at the same time
Theoretical and analytical calculations on paper to assess the foundation and physics behind the reservoir behavior
Phenomenological models to understand the main drivers and reproduce the flow mechanism with a more flexible tool
Regional geology and migration history to estimate untested parameters away from the oil pool especially inside the aquifer
An iterative and innovative Static-Dynamic integrated process to generate a reservoir characterization honoring geology and performance at the same time
The applied workflow revealed for the first time the magnitude of the natural energy of the reservoir that contributes significantly (15-20%) to the energy loss. A revelation that changed the reservoir development strategy going forward. It inspired innovative methods to capture horizontal and vertical permeability needed to reproduce field performance on surface and flow dynamics inside the reservoir.
This comprehensive and integrated workflow generated a reliable and sustainable tool and put in place different technics to achieve an updated history match relatively quickly.
ADNOC Offshore started-up full field gas-lift activation for the first time in 2020. This major step will unlock field's potential by increasing reservoir withdrawal and increasing wells life by mitigating water production / breakthrough. This paper details the successful application of gas-lift from design during appraisal phase and early production stage to full field implementation. Fit for purpose design was implemented through multi-disciplinary studies and work. A strong change management in operating philosophy was requested to take onboard all stakeholders: Field development, Field Operation, Wells operation, Drilling and completion. Following appraisal and early production phases on a green field, wells design was optimized to ensure proper activation in most of the producers (two over three reservoirs developed). Due to full field development phasing, the first 30% of the wells completion were designed based on early production phase data. Before full field commissioning started, in well gas-lift valves were designed and installed, integrating all the dynamic information gathered during natural flow production. Valves change out was performed with the highest HSE standards, and taking into account full field development timing in order to reduce downtime and therefor maximize production. As gas-lift is new in the operating company, a strong change management was required: operating with gas-lift by field operation team, Completion design, Drilling and Gas-lift Production with SIMOPS. Gas Lift implementation will ensure the future oil production of the field as water injection and production will increase. Gas-lift practice implementation led to modifying the operating company's rules in multiple and deep aspects:
Improve field team competencies in handling high pressure gas-lift system, Increase completion and wells operation complexity, Implement new SIMOPS rules.
Improve field team competencies in handling high pressure gas-lift system,
Increase completion and wells operation complexity,
Implement new SIMOPS rules.
As a first achievement, one well under reservoir integrity issue (low productivity due to reservoir collapse) was re-activated and production of existing wells was increased of several thousands baril. Further increase in production is expected in the following months as implementation is deployed to all required wells.
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.
Saqib, Talha (ADNOC Offshore) | Grifantini, Simona (ADNOC Offshore) | Sabri, Abdel Mouez M. (ADNOC Offshore) | Keshtta, Osama M. (ADNOC Offshore) | Albadi, Bader S. (ADNOC Offshore) | Beaman, Daniel J. (ADNOC Offshore) | Al-Hassani, Sultan D. (ADNOC Offshore) | Bigno, Yann (ADNOC Offshore) | Draoui, Elyes H. (ADNOC Offshore)
Field presented here is located in the southern part of the Arabian Gulf approximately 135 km north-west of Abu Dhabi city. This giant heterogeneous carbonate field consists of multi-stacked reservoirs. The presented reservoir is highly fractured, it measures 9 km by 11.5 km.
The reservoir has an original oil in place estimated at 2,240 MMstb of 35°API oil with saturation gas of 400 SCF/bbl. The reservoir pressure is +/− 2,700 psi and the sealine pressure in the field is +/− 1100 psi. The wells completed in T reservoir are unable to flow naturally against the high sealine pressure. Some wells are producing against by-pass line at 600 psi. Crestal gas injection was introduced to maintain the reservoir pressure.
To produce the reservoir at its potential, it is required to use some artificial lift techniques. ESP was finalized to install for overcoming the high sea line pressure.
As mentioned earlier the T reservoir is naturally fractured and has crestal gas injection, which lead towards 3,500 – 4,000 SCF/bbl and beyond the ESP limit. This requires some solution to handle the gas.
A collaborative team of engineers was assigned to design and meet the challenge of such a premier application. The team conducted a detailed and comprehensive analysis of the T reservoir's fracture and fault characterization: the aim was to deliver an optimal well design meeting the requirement of ESP gas handling with minimum cost.
A unique, fit-for-purpose dual completion (4-1/2" × 2-3/8") was finalized. The rigless ESP will be run through 4-1/2" tubing and 2-3/8" tubing will be utilized for gas handling and re-injecting gas in the sealine at surface. The dual completion will allow to handle high GOR through short string, which will lead towards the long ESP runlife.
Before commencing the full development plan for T reservoir, this will be a pilot for better understanding the reservoir and its behavior.
Rigless ESP was selected due to the advantages compared with conventional ESP: POOH and RIH of retrievable ESP parts through a conventional slickline unit Pumps can be replaced during the well life without rig workover. Low OPEX cost.
POOH and RIH of retrievable ESP parts through a conventional slickline unit
Pumps can be replaced during the well life without rig workover.
Low OPEX cost.
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).