The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
- Data Science & Engineering Analytics
The SPE has split the former "Management & Information" technical discipline into two new technical discplines:
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A consortium led by TotalEnergies will start drilling for oil and gas off the coast of Lebanon at the beginning of September, the country's Caretaker Energy Minister Walid Fayyad said, according to Reuters. The consortium, which includes partners Eni and QatarEnergy, has assigned a rig for the offshore southern bloc known as Bloc 9. "The rig will start working in Lebanon in September ... before the end of the year we will know if there is a discovery," Fayyad told reporters at the World Utilities Congress in Abu Dhabi. Fayyad said a potential discovery could impact whether a deadline for applications to explore in eight additional offshore blocs is extended yet again, past June. "I have been hearing from players in the field that they are keen to see the result of the drilling in Bloc 9 before they make decisions as to further investments or commitments in Lebanon," he told reporters. The minister said Lebanon would aim to boost imports from Iraq by bumping up the volume of an existing swap deal and through new commercial agreements.
The Abu Dhabi National Oil Company (ADNOC) and the Abu Dhabi National Energy Company (TAQA) have announced a major project requiring an investment of up to 2.4 billion to build a sustainable water supply for ADNOC's onshore operations. The infrastructure initiative includes the construction of a centralized seawater treatment facility and transportation network for the Bab and Bu Hasa fields in Abu Dhabi which combine to produce more than 1 million B/D. In 2021, ADNOC said it would spend more than 300 million on a multiyear project to install remotely controlled production systems in up to 260 conventional and unconventional wells in the Bu Hasa field. The Bab field has a capacity of over 450,000 B/D and is in the midst of a major enhanced oil recovery project that aims to increase production capacity to 485,000 B/D. The major capital program planned for both fields is seen as part of ADNOC's wider strategy to boost the UAE's production from 4 million to 5 million B/D by 2030.
Fukuda, K. (ADNOC Offshore) | Biyanni, H. (ADNOC Offshore) | Toma, M. (ADNOC Offshore) | Moslim, S. (ADNOC Offshore) | Toki, T. (ADNOC Offshore) | Zaabi, A. Al (ADNOC Offshore)
Abstract Hollow bit method was introduced and implemented in Offshore Abu Dhabi Field to eliminate the cement quality uncertainty and improve the slot recovery performance. Hollow bit method improved the overall slot recovery performance by 40% compared to other slot recovery methods, reducing operation duration from 20.8 days to 12.5 days. In this paper, hollow bit technical overview and best practices which can be implemented to similar application are presented
Krikor, Ara (ADNOC Offshore) | Bimastianto, Paulinus Abhyudaya (ADNOC Offshore) | Khambete, Shreepad Purushottam (ADNOC Offshore) | Cotten, Michael Bradley (ADNOC Offshore) | Toader, Lucian (ADNOC Offshore) | Landaeta Rivas, Fernando Jose (ADNOC Offshore) | Duivala, Shahid Yakubbhai (ADNOC Offshore) | Mughal, Muhammad Idrees (ADNOC Offshore) | Al Ameri, Suhail Mohammed (ADNOC Offshore) | AlMarzooqi, Adel AbdulRahman (ADNOC Offshore) | Chevallier, Bertrand (SLB) | Vallet, Laurent François (SLB) | Ullah, Nadeem Hidayat (SLB) | Qadir, Ahsan (SLB) | Al Khufash, Hassan Walid (SLB) | Shareef, Raneef Mohamed (SLB) | Ul Islam, Muhammad Ashar (SLB)
Abstract Digital Twin has become pillar of Oil and Gas industry. Previously, there was no solution / tool available to detect early bit failure, therefore Real Time Operations Centre (RTOC) team decided to develop and implement Mechanical Specific Energy (MSE) Ratio in real time to detect drilling dysfunctions and consequently prevent Non-Productive Time (NPT). The paper aims to demonstrate how MSE ratio helps to enhance the performance efficiency in real time while drilling operation. RTOC aggregates data from all the operational Rigs in real time and digital twin solution was developed to compute MSE Ratio in real time from downhole and surface MSE. Automated Machine Learning workflows compute downhole Weight on Bit and downhole Torque to compute downhole MSE. Surface MSE is automatically computed based on surface parameters. Output is filtered with Machine Learning Rig State workflow to avoid any false computation. The algorithmic outputs are calculated in time dataset and then converted to depth-based data in real time. Trend analysis of outputs will help to identify inefficiency and take decision on time. The Dynamic Solution can be used as smart drilling decision tool to detect bit performance abnormality and to enhance the efficiency for drilling operation. Trend of MSE Ratio output has helped to identify the bit failure in real time which further paves the way to decide bit trip and optimize the performance of the well. Case Study will demonstrate where trend of MSE ratio reached below the defined baseline and provided alert for potential bit failure. Bit trip was performed and based on bit dull grading, it was decided to run with new bit. MSE ratio observed on the new bit reached back to normal trend as per defined baseline. New bit was able to drill and complete the section within the plan. This tool has been implemented successfully on all the operational Rigs to monitor performance in real time and can help to take decisions to safeguarding and optimize the performance of the sections and well. Trend analysis of MSE Ratio along with other parameters can help to detect inefficiency and optimize rate of penetration (ROP) in real time. This innovative approach of using MSE Ratio can help to build new digital twin solutions and enhance utilization of MSE output. Machine Learning workflows leverages the objective of digital drilling transformation and to optimize drilling efficiency in real time. Output helps to improve performance and prevent unwanted events. Solution can be further enhanced to detect other drilling dysfunctions and define efficiency roadmap with the combination of Drilling Strength.
Abstract Tubular GRE lining technology has been globally applied used since 1960's in eliminating downhole tubular corrosion, replacing the elevated CAPEX of CRA OCTG and assuring steady oil, gas and water flow through the downhole string with its flow assurance benefits. Compared to conventional carbon steel whose failures are frequent, the GRE lined carbon steel provides long lasting protection which results in huge savings in life cycle cost. Likewise, compared to CRA material capable of withstanding corrosion issues, the GRE lined CS provides direct capital cost savings. Apart from the economic benefits, operators deploying GRE lined CS have enjoyed superior well integrity over the life cycle of the well. Abu Dhabi National Oil Company (ADNOC ONSHORE) implemented this technology in 2013 for the water disposal wells (5 wells as trial, all of them were successful). We will share the results of the caliper logs that have been run into these wells and the inspection of tubing pulled out of the disposal wells after 4 years in service. Following the assessment, which was satisfactory, the first Water Injection well with GRE lined tubing has been RIH in 2021, and plans for Oil producers with GRE lined tubing in Q2-2023. Till the time of writing this paper, 19 GRE lined strings have been RIH in Aon's water disposal wells, and 2 strings have been run in water injection wells (under study and field test and assessment). This paper shares the evolution of this technology within the Aon from the first installation to the development of a contract and how Aon geared to absorb this technology in their system. Some of the challenges that faced the company were: The modifications that were required to the wells’ designs. How the service provider was aware of Aon's operational well intervention jobs. How this is compatible with the lining system.
Varma, Esha Narendra (ADNOC Onshore) | Ditzler, Theodore Jay (ADNOC Onshore) | Mwansa, Peter Levison (ADNOC Onshore) | Husien, Mohammad (ADNOC Onshore) | Bahrom, Abdul Raman Bin (ADNOC Onshore) | Saragi, Raymond (ADNOC Onshore) | Samahi, Musabbeh Khamis Al (ADNOC Onshore) | Shamsi, Juma Sulaiman Al (ADNOC Onshore) | Alshaigy, Ahmad Othman (ADNOC Onshore) | Gaurav, Anchit (Churchill Drilling Tools) | Abdelhalim, Khaled (Churchill Drilling Tools)
Abstract Extended reach drilling (ERD) can facilitate the development of untapped resources, reduce greenhouse gas emissions, surface congestion, and drilling costs. This ERD project with lower completion was started with an aim to lower well cost indicators including $/ft and $/bbl. Therefore, the challenge was to drill Slimhole ERD (6-1/8″ lateral) wells with water-based mud (WBM). WBM is more cost-effective, environmentally friendly, and less damaging to the reservoir than OBM (oil-based mud). The use of WBM instead of OBM can save $2MM per well. The major challenges in drilling Slimhole (6-1/8″ size) ERD well with lateral le include higher torque and failure to deploy lower completion due to high friction factors. The first pilot well was planned with a liner-less design considering the low friction factors required to drill 15,000′ of 6-1/8″ lateral hole and run the lower completion. The second pilot well was targeting a deeper and tighter reservoir zone with higher downhole temperatures. This involved drilling 12-1/4″ intermediate hole to the landing point with larger 5-1/2″ drill pipe. It enabled a push-pipe technique for drilling the lateral hole with improved weight transfer through the curved profile. The 6-1/8″ lateral hole was drilled with 4″ high-torque drill pipe, tandem high-flow circulating subs, and specially formulated drilling fluid lubricant. A conventional OBM system provides sufficient lubricity to reduce friction factors as low as 0.10. In this application, a low cost WBM system was made feasible by introducing stable high-temperature lubricant and unique hole cleaning practices. Following this successful achievement, the 5-year business plan has been revised to include 63 similar wells with a projected total savings of ~ $250MM. The Slimhole ERD project has demonstrated substantial value with a 35% reduction in CAPEX. The delivery of these two Slimhole ERD wells overturned conventional drilling and completion practices. The implemented project resulted in saving up to 35% of the well cost and saved 20 days per well compared to a conventional ERD well with 8-1/2″ hole and OBM. These two Slimhole ERD (15,000′ lateral) wells were drilled with a challenging Directional Difficulty Index (DDI) of 7.2. The wells were both completed successfully by running the 4-1/2″ lower completion to reach the total depth.
Akinlosotu, Akintunde Olaniyi (ADNOC Onshore) | Quintero, Fernando (ADNOC Onshore) | Baruno, Agung (ADNOC Onshore) | Al Rahma, Rahma (ADNOC Onshore) | Al-Jabery, Razan (ADNOC Onshore) | Al-Reyami, Mazin (ADNOC Onshore) | Bin Shamlan, Abdulla (ADNOC Onshore) | Ali Al-Bunni, M (Baker Hughes) | Yehia Mahmoud, Mohamed (Baker Hughes) | Ud Duja, Badar (Baker Hughes) | Arshad, Hafiz (Baker Hughes)
Abstract Traditionally, the standard procedure employed by ADNOC Onshore for re-entry wells sidetracked from a cased hole involved milling a window in the casing and followed by a dedicated elongation run with a mud motor bottom hole assembly (BHA) for kick-off and to achieve desired separation from the original casing/wellbore before pulling out of hole with the motor drilling assembly. This is then followed up with a rotary steerable plus measurement/logging while drilling (M/LWD) assembly to continue drilling the 8-1/2″ deviated section to target landing point (LP). The main reasons for having the dedicated motor elongation run are to get enough separation from the main wellbore (not tracking the original hole) within the shortest distance to avoid the magnetic interference to the M/LWD tools from the casing and to assure not following the previously drilled well. However, associated with this practice are some negative impacts operationally which can be summarized as below –High localized dogleg severity (DLS) during the sliding interval with the motor –Requirement to make-up and round-trip two separate BHAs before drilling to planned LP –Potential hanging of the motor assembly at the window during sliding interval –Additional cost due to utilizing 2 different types of drilling bit (Initially TCI for the motor run and then PDC to drill the section) The only way to avoid those cons is by doing one trip with RSS to exit the window and drill away from the whipstock. The main challenge doing this will be to have enough rat hole to accommodate the BHA (including smart tools with electronics parts) and avoid damaging the BHA components during rotating it inside the casing. This can and has been achieved with a high build rate RSS by some operators but however, use of this technology still exposes the delicate components of the M/LWD tools to possible damage due to contact with the window while rotating the string with the tools still within the parent casing. The introduction of the motorized rotary steerable system (MRSS) in the suite of steerable drilling assemblies has opened additional window of opportunities. Ability to combine some of the benefits of using a mud motor with that of a rotary steerable system all in one bottom hole assembly without doubt offers the potential of pushing further the limit of performance and productivity. With the MRSS BHA, with a minimum required rathole drilled with the whipstock milling assembly, the rotating part of the BHA will be out of the window prior to start circulation. This paper presents the success achieved with a MRSS system with Near bit Gamma-ray sensor requiring only 18ft rat hole delivered in ADNOC Onshore re-entry wells sidetracked from whipstock window.
Fujinaga, Ryota (ADNOC Offshore, Abu Dhabi, UAE) | Toki, Takahiro (ADNOC Offshore, Abu Dhabi, UAE) | Toma, Motohiro (ADNOC Offshore, Abu Dhabi, UAE) | Andrews, Kerron Kerman (ADNOC Offshore, Abu Dhabi, UAE) | Alloghani, Khalid Hussain (ADNOC Offshore, Abu Dhabi, UAE)
Abstract Concept Select and Preliminary Front End Engineering and Design (Pre-FEED) were carried out on a long-term development plan (LTDP) for a brown oil field with nearly 200 existing Wellhead Towers (WHTs) and four existing artificial islands in the middle east area. The development objective is ramping up the production to certain rate and sustain it as long as economically feasible. This paper will describe: Critical stuff that needs to be performed or taken into account from drilling perspective during Concept Select/Design and Pre-FEED How the drilling discipline should be proactively engaged through Concept Select and Pre-FEED for development project of offshore brown oil field During the Concept Select, necessary data related to drilling was firstly collected such as well target locations, available slots on existing WHTs etc. In addition to that, several assumptions were set, associated with drilling rig specifications, constraints on drilling feasibility and number of well slots on new WHT. Based on the data and assumptions, multiple concepts were developed with respect to different drill centers including new WHTs, new artificial islands and existing WHTs/islands in coordination with other disciplines. Techno-economical evaluation was conducted on each concept. Subsequently, Pre-FEED was conducted based on the selected concept. During the Pre-FEED, more detailed study on WHT locations, WHT orientations, WHT design, island location, island design, HSE assessment etc. was conducted by Pre-FEED contractor, incorporating basis and requirements from all the concerned disciplines. Through the Concept Select and Pre-FEED for Long Term Development Plan (LTDP), following things were found important: Generic drilling limits like maximum horizontal departure to targets should be defined clearly at early timing of Concept Select for optimization of well allocation to drill centers Rig specifications and its limits like air gap, skidding envelope and allowable drilling load should be identified at early stage for optimization of WHT design/locations and island design Slot-to-slot distance and row-to-row distance are quite important especially for island in terms of rig operability on island and anti-collision between wells Requirements for area and its arrangement on island should be well defined item-by-item to avoid shortage in the area dedicated for drilling during subsequent stage of project Anything that needs to be studied or considered by Front End Engineering and Design (FEED) contractor should be captured in FEED Scope of Work (SoW) with detailed requirements, which will be utilized for tender process. Anything that is not captured in the FEED SoW could result in variation order or be difficult to be added to the scope after contract award. This paper will present not only the experience in this specific project but also a fundamental approach that will be applicable in any other offshore brown oil fields worldwide.
Yudhia, D. P. (ADNOC OFFSHORE, Abu Dhabi, UAE) | Seyfetdinov, R. (ADNOC OFFSHORE, Abu Dhabi, UAE) | Alhaj, M. (ADNOC OFFSHORE, Abu Dhabi, UAE) | Aziz, M. Abdel (ADNOC OFFSHORE, Abu Dhabi, UAE) | Rabis, P. (ADNOC OFFSHORE, Abu Dhabi, UAE) | Al Ameri, S. M. (ADNOC OFFSHORE, Abu Dhabi, UAE) | AlMarzooqi, A. (ADNOC OFFSHORE, Abu Dhabi, UAE) | Barbera, R. (Dril-Quip, Abu Dhabi, UAE) | Sallam, S. (Dril-Quip, Abu Dhabi, UAE) | Omar, H. (Dril-Quip, Abu Dhabi, UAE)
Abstract Liner hanger operations and well integrity across the liner overlap have been always a challenge in the gas well. Conventional liner hanger relies on elastomeric devices as the primary sealing mechanism to isolate the liner lap strings, with two trips required to deploy the liner hanger, top packer and tie-back seal. This paper will introduce an expandable liner hanger/packer and tie-back system to isolate high pressure reservoir and problematic shale in Offshore Abu Dhabi. The selected single-trip expandable XPak liner hanger/packer and tie-back system offers a metal-to-metal seal throughout the complete liner stack, with 17 to 24 inches of an expandable section on the hanger/packer body that generate sufficient metal-to-metal contact area between the liner and the host casing achieving a robust sealing device that is to be considered as a primary isolating barrier. Feasibility review of technology was then conducted, covering review of running procedure, risk assessment and success criteria (covering HSE, performance, integrity, and efficiency). Business case was issued to install the 13-3/8″ × 9-5/8″ system. The system was deployed in a gas well drilled in 2021. Cementing job of 9 5/8″ liner was conducted smoothly with liner string rotated at 10 rpm while pumping & displace cement. Liner hanger/packer was set with 4,400 psi, hanger setting was then confirmed with 70 klbs overpull and the setting tool was released by slacking off the drill string with 120 klbs. The operation was conducted safely and with zero NPT. The system was successfully demonstrated by the effectiveness of the offered features and its running procedure. Liner and tie-back casing integrity was achieved and confirmed through successful pressure tests. Based on the trial result, the selected single-trip expandable liner hanger/packer and tie-back system achieved the defined success criteria. The actual time saving from deployment of single-trip expandable liner hanger/packer and tie-back system compared to conventional liner hanger in this application is 2.54 rig days. The detailed analysis and operation feedback will be beneficial to assess the suitability of this technology to overcome future drilling and integrity challenges.