bluuebunny/crossref_metadata_2025_split huggingface dataset:
Unlocking Potential of a Shuaiba Reservoir Field Through Accelerated Field Development and Utilization of New Technologies in Geosteering and Production Optimization
Authors: Kindi Z. A Al , Balushi A. AL 
Published: October 2023

Abstract
Shuaiba formation is one of key reservoirs around Oman. Most of big Shuaiba plays are developed since the early days, however some plays were discovered and ranked as low recovery plays. Our focus is to highlight key elements were applied to unlock and accelerate development of one of those fields.
The first exploration well was drilled targeting deep Gas reservoirs, the vertical hole shows an indication of HC within XX Shuaiba play. XX Shuaiba play was low relief structure which remains the key risk, so an appraisal well drilled vertically to assess the potential followed by lateral well to perform productivity test.
As a result, from few appraisal wells around the field, the key challenges were:
Project funding constrains. Steering the wells close to the roof. The reservoir permeability is high, and water is highly mobile. Crude processing Capacity limitations. Produced Water handling. Optimization of wells hook-up process.
To overcome and accelerate the project, a strategic note submitted to get a fast approval for the updated FDP. Project strategy to minimize the cost by have rental stations and optimize cost of wells drilling and surface constructions.
Well placement was continuously improved by implement different logging solutions (ex: Borehole imaging, Roof indicators …etc.). However, placement is also critical to delay water productions as the zones are vertically connected so mechanical shutoff implemented (Ex: scab liner, straddle packers… etc). In line with subsurface solutions, in surface for wells with High potential and low water cut an extended well test unit were carried on also an introduction of mini station has maximized and accelerate crude production and processing. In addition, major project established to handle the capacity of water and ramp up oil production. To fasten hookup process, LLRTP flow lines commissioned to connect wells to MSV also mobile DG used to power artificial lift down hole equipment till commissioning of OHL.
The project recovered the cost in around 5 years with sustained oil production to date.
Novel Approach of Reservoir Management to Ensure Reservoir Healthiness and Gas Availability to the Network
Authors: Yaqoubi Nouf Al , Sudarev Maxim , Hammadi Shamma Al , Marzooqi Laila Al , Latypov Eduard , Hosani Mariam Al , Bairaq Ahmed Al 
Published: October 2023

Abstract
This study presents a state-of-the-art approach to enhance the development of a giant gas-condensate reservoir in the UAE. The primary objective is to maximize condensate recovery and maintain reservoir pressure while also focusing on decarbonization and emission reduction. With the combination of productivity growth and sustainable strategy, multiple measures were taken to diminish the necessity of drilling new wells and drilling related facilities. The study specifically focuses on the recycling mode in the reservoir, aiming to achieve high condensate recovery and reservoir pressure maintenance by dividing the reservoir into distinct sectors. This approach is particularly valuable during under-injection mode when there is a lack of make-up gas or a need to produce sellable gas. Proper distribution of available gas for injection is crucial for maintaining reservoir pressure where it is most needed and preventing premature gas breakthrough. The study's main goal is to sectorize the reservoir based on geological definitions and optimize well-level strategies, including the redistribution of injection and full-field development plans. To accomplish this, geological data such as facies are utilized initially, followed by the use of actual tracer and production/injection data to validate the sectorization. This work has yielded positive results, leading to an increase in condensate recovery by several million units without requiring additional investments. Based on the outcome analysis, an implementation plan has been devised, specifying allowable gas injection rates for each gas injector. Overall, the implementation of this approach has resulted in a significant increase in condensate recovery and an extension of the gas production plateau.
Further optimization the performance was achieved by conducting horizontalization of the vertical wells with low condensate gas ration (CGR). The horizontalization strategy resulted in minimization of reservoir contacts and enhancement of productivity. Based on the sectorization concept, peripheral drilling was carried out targeting the upswept rich condensate zones. In summary, under the sectorization strategy, horizontalization, low CGR well optimization, and peripheral drilling were combinedly carried out resulting in improvements of ultimate recovery and production efficiency. The sectorization implementation added gain of ∼ 0.5% on the URF. The horizontalization added gain of ∼1.5% and ∼ 4 % from the Peripheral project. Overall, the condensate URF was enhanced by ∼ 5- 6%
Using a Permanently Installed Fiber Optic Sensing System for Water Injection Monitoring on an Onshore Water Injection Well in a Carbonate Reservoir
Authors: Mason J. , Naldrett G. , Venkata S. Rachapudi , Ofowena F. , Rios J. Vargas , Ahmed J. , Mahmood H. , Langnes T. 
Published: October 2023

Abstract
A series of fiber optic surveys were performed in an Onshore well in Abu Dhabi to prove the concept of using both Distributed Acoustic Sensing (DAS) and Distributed Temperature Sensing (DTS) for water injection monitoring.
This technology aims to provide new and novel techniques where these surveys could be carried out without wellbore intervention, thereby reducing cost, removing HSE risk and lowering carbon footprint. In addition to these significant benefits fiber optic data provides a dense array of measurements from surface to total depth.
The well selected for this proof-of-concept pilot was an onshore horizontal water injector located south of Abu Dhabi. Total depth of the well is approximately 13,000ft, of which approximately 5,000ft is an open hole injection interval. The fiber optic cable was clamped to a 3.5″ tubing string at the time of completion, all the way from surface to total depth. The reservoir section was completed open hole with slotted 3.5″ tubing below the production packer allowing injection through perforated pipe into five separate intervals, each isolated by four swells packers.
DAS and DTS data were recorded on the first injection into this well. Although water injection had started in the field the project team obtained dispensation from the reservoir management team to keep the well shut in until fiber optic acquisition could be acquired. This allowed a stable geothermal baseline to be obtained, and after initial injection the well only had to be shut for a few hours to obtain a good warmback response.
Unearthing Hidden Treasures Beneath Our Feet: The Thrilling Journey of Recent Oil Field Discovery and Charting Future Opportunities, Onshore Abu Dhabi
Authors: Salahuddin A. A. , Al-Ghaferi M. R. , Khan K. A. , Warsito E. , Aljneibi N. M. 
Published: October 2023

Abstract
This paper presents a case study of the successful discovery of an appraisal well on a fault-bounded oil accumulation, carried out recently. The discovery was made adjacent to two big mature fields, highlighting the importance of careful geological and geophysical evaluation in identifying and targeting untapped potential hydrocarbon reserves. This paper also showcases the pre-drilled estimation of the probability of success (PoS) to properly evaluate the risk associated to the prospect and improve drilling success.
The study involved a comprehensive and thorough evaluation of geological, geophysical, and petrophysical data to understand the complexities of the petroleum system elements of the prospect. A range of advanced geoscience techniques were utilized, including seismic interpretation, advanced seismic imaging, well log analysis, core analysis, structural analysis, basin modeling, and play fairway analysis to develop a detailed understanding of the petroleum system elements of the area. This enabled the identification of high-quality potential hydrocarbon accumulation target in the fault-bounded reservoir. The appraisal well was drilled vertically using the latest drilling technologies and advanced data acquisition programs that allowed for better understanding on the reservoir characterization.
The well intersected significant oil column thickness with good reservoir properties and the oil was of good quality. The discovery of the fault-bounded oil accumulation was a significant achievement, highlighting the analysis of drilling data, mud log, well logs, and production testing data to further understand the reservoir potential and productivity for field development plan purposes. The discovery also demonstrated and provided valuable insights into the importance of careful geological and geophysical evaluation in identifying and targeting potential hydrocarbon traps and reserves with same geological setting and trap concept in other onshore areas.
The success of the appraisal well discovery on a fault-bounded oil accumulation demonstrates the importance of utilizing a range of advanced geoscience techniques to understand the complexities of the petroleum system elements of the prospect. This allows for the identification and targeting of potential hydrocarbon traps, and ultimately, the successful discovery of new reserves.
Stratigraphy and Depositional Environments of the Paleogene Pabdeh Foredeep Basin: A Shallow Shelf to Deep Basin Transect, Ras Al Khaimah, UAE
Authors: Mills W. S. , Socha K. , Malczewski M. , Swire P. H. , Firpo G. , Balta A. O. , Burckhart T. , Kepinski M. , Ryder R. , Cetean C. , Sekti R. , Pardon A. , Mccarthy A. , Gold D. P. , Holloway D. , Hadro P. , Hjalmarsdottir H. , Hayward P. 
Published: October 2023

Abstract
The present study is the result of a technical collaboration undertaken by RAK Gas (the national energy company of the Emirate of Ras Al Khaimah, UAE), PGNiG PKN ORLEN (current operator of RAK Block 5, Figure 1) and CGG.
The research focuses on the Paleogene Pabdeh Group, the thick sediment package that filled the accommodation space developed during the Northern Emirates foreland basin evolution (Figure 2). The main goal of the study was to create an integrated stratigraphic framework and regional understanding of the Late Cretaceous and Paleogene depositional system by describing age, facies distribution and depositional environment of the Aruma and Pabdeh sequences, within the Oman Mountain foreland basin.
The Pabdeh Group encompasses a variety of lithologies related to different sediments sources and depositional settings, revealing a rather complex tectono-stratigraphic evolution. A correct understanding of such sedimentological diversity is critical to develop an effective hydrocarbon exploration strategy, including multiple reservoir targets, play concepts and exploration scenarios. To date, a relatively limited number of research papers has focused on the Pabdeh potential, mostly because the oil and gas exploration and production in the Northern Emirates has been historically limited to the Cretaceous carbonates of the Arabian Platform.
New data acquisition carried out in the last decade in the Ras Al Khaimah (RAK) acreage (i.e. onshore 3D seismic, FTG/Aeromagnetics) contributed to generate a rejuvenated interest in the Cenozoic plays, which has allowed a leads/prospects portfolio to be developed in the Paleogene section and led, in 2023, to the drilling of the first exploration well targeting the Pabdeh Group (Oryx-1). Several authors who have utilized the recently acquired data, published novel research material on the UAE foreland potential including Fava (2018), Firpo (2020 and 2021), Swire et al. (2022).
Near Bit, Real-Time 1D and 3D Ultra-Deep Resistivity Inversion; A Case Study in the Longest Maximum-Reservoir-Contact well Offshore Abu Dhabi, UAE
Authors: Serry Amr , Ahmed Shafiq , Arif Abdelrahman , Keshta Osama , Yousif Sharifa , Alhamedi Asma , Cottin Christophe , Fares Wael , Manurung Vinda , Waseem _ , Clegg Nigel 
Published: October 2023

Abstract
For decades, horizontal wells, offshore Abu Dhabi have been planned and executed with the objective of enhancing well productivity, injectivity, and to reduce water coning. One of the main methods of maximizing reservoir contact is through targeting two reservoir layers in one horizontal section. To enable these specific targets, the implementation of innovative geosteering solutions has a major role in securing the success of the project. Early warning and deep horizon mapping is critical, therefore we demonstrate the innovation of the placement for the Ultra-deep azimuthal resistivity (UDAR) logging while drilling (LWD) transmitter close to the bit.
The subject well targets two carbonate reservoirs layers by drilling a single eight and half inch, horizontal section. The drilled footage along each formation was approximately 4000 ft of lateral length with a total length of 8000 ft measured depth. Consequently, a six- and three-quarter inch OD UDAR tool has been combined with a triple combo bottom hole assembly, in order to enhance the well placement, with the aim of simultaneous geosteering and GeoMapping using advanced 1D inversion processing in real-time. In geosteering operations early decision making allows for more gentle corrections to be made, limiting tortuosity, critical in very long wells. The latest technology, allows deployment of a UDAR transmitter close to the bit in this study ~25 ft. Providing both UDAR inversions and actual Shallow Phase / Attenuation Resistivity measurements.
The Well encountered multiple geological and drilling challenges during the real time drilling operations. Despite the evident complexities in density images, which indicated the undulation of the formation, the 1D UDAR Inversions clearly identified the stratigraphic position of the well allowing for optimal well placement decisions to be made early due to the proximity of the UDAR transmitter to the bit. Additionally, the 1D inversions allowed early identification of a conductive zone below the trajectory at the heel as well as a conductive zone above the well trajectory towards the toe. This was interpreted as water coning / slumping, vividly displayed in the UDAR azimuthal resistivity image, 1D Inversion and 3D inversion, the direction of the low conductive zone was coming from the left-top side of the trajectory, indicating alignment with the nearest offset well.
The 1D/3D inversion data provided has increased confidence for the completion team to finalize blanking sections and pump design in a timely manner to isolate the zone at risk from water breakthrough. This successful run with regards to both operations and safety has set a benchmark for future development for saving operation time and cost.
Efficient Solutions to Reinforce Weak Soil Strata
Authors: Nuthanapati Sreekanth , Subramanian T. S. , Al Awadhi Ibrahim 
Published: October 2023

Abstract
Site selection for Industrial / Oil & Gas plants is a complex process requiring careful consideration of numerous factors to render it technologically and economically viable. Any error committed during selection of plot will have short- and long-term ramifications in terms of cost, safety, operability etc. This paper presents the issues faced in development of pre-finalized project plots and improvements that are carried out in most effective and economical way for safe functioning of the plant.
Geotechnical investigations were conducted to obtain soil characteristics at different depths of predefined bore hole locations at each of the project plot. Also ground water levels were measured at each of the bore hole location to establish the ground water level to identify the measures to be considered during design and construction.
In some project plots / unit plot areas, liquefaction risks were anticipated due to presence of loose silty sand layers in the event of earthquake. This may result in differential settlement of structures and equipment supported and the same will affect the operation and long-term integrity of that unit / plant. In some other unit plots, allowable bearing pressure at proposed founding level is not adequate to support the heavy loads from equipment.
Removal of these silty sand layers at varying depths (5 to 7.0m) and replacing with compacted engineering fill is one of the options, however not pursued due to time and cost. Project / unit plots were finalized based on soil properties, type of structures and anticipated loads etc., and cost benefit analysis was performed for different geotechnical solutions to identify optimal soil reinforcement solution.
Due to presence of weak soil in large storage areas with liquefaction potential, soil improvement using ‘vibro-replacement’ technique was finalized to prevent excessive / differential settlement and to improve allowable bearing pressure.
State-of-the-art soil stabilization technique using geo-synthetics to increase the stiffness of weak soil was employed in other project / unit areas intended to support moderately loaded facilities. Removal of loose topsoil and replacement by ‘Engineering Fill’ supplemented with adequate compaction was deemed sufficient in certain areas bearing lightly loaded facilities.
By tailoring different geotechnical solutions that suits the unit / plot soil conditions, expensive soil improvements & large/raft foundation solutions were eliminated. As a result, foundation footprint and concrete quantities were optimized which resulted in substantial savings in construction cost and improvement in project schedule due to elimination of laborious activities.
Ultra ERD Well Completions: Extending the Limits to Drive Profitability
Authors: Panga M. K. , Al Hammadi F. , Marsh J. D. , Mohamed A. , Pace D. , Wills J. 
Published: October 2023

AbstractThis paper discusses the new technologies and completion methods implemented to complete ultra-ERD wells in a giant carbonate reservoir with total depth reaching fifty thousand feet. The wells are drilled from an offshore island and completed with a compartmentalized limited entry liner in the reservoir section. The ability to reach reservoir targets farther away from the island has brought significant cost benefits by deferring the need for a new island to develop the reservoir.With lateral section length exceeding thirty-five thousand feet, several initiatives were taken to be able to deploy the liner to bottom. A comprehensive risk analysis showed that injection and production from neighboring wells resulted in a highly uneven reservoir pressure along the lateral which increased the differential sticking risk while running the liner. To mitigate the risk, neighboring wells were shut-in ahead of time and pressure measurements were taken during the drilling phase to optimize the mud density and reduce the overbalance during liner run. The second challenge was to minimize friction to be able to slack-off the liner without helically buckling or losing hook load prematurely. To achieve low friction factor, non-aqueous mud (NAF) was used, and hole cleaning practices were implemented during drilling phase to remove cuttings and debris from the lateral section. As a contingency measure to address unexpected high friction factors, a casing swivel was also included in the liner to enable rotation and reduce friction load.
Integrated Drilling Services Model Driving Cost Optimization and Operation Efficiency
Authors: Al Hadabi Faisal , Al Rashdi Zakiya , Al Bulushi Mohamed 
Published: October 2023

Abstract
An outcome-based contract is an agreement between a client and a contractor in which the contractor is contracted to deliver business results rather than providing services without being accountable for the deliverable. Such business results can be, for example, completed wells which meet pre-agreed acceptance criteria. The IPM approach is a typical example of an Outcome Based Contract. In such contracts there are minimum client/ contractor interfaces, and the contractor has a vested interest in optimizing performance as payment is linked to pre-defined acceptance criteria for the deliverable; these criteria, such as, completed well, are collated in checklists. Continuous improvement, drilling efficiency, and consistency are critical components in an integrated project for achieving drilling performance and ensuring project profitability, whereas the customer establishes a goal of expediting well deliveries in a safe and efficient manner by deploying new technologies and advanced engineering practices, which results in drilling efficiency optimization (Abdelaal, K. et al. 2022).
As an example of the outcome-based approach is the development of Marmul Phase III Polymer Project under an IPM Model. The strategic objective is to deliver 800+ wells safely, on time and meeting PDO specifications in Marmul; Greater Saqar and Standardize Satellite Field Development (SSFD) fields. The main value drivers are to deliver wells safely, reduce well cost– Cost Target, secure production promise to shareholders – phasing/timings and quality. The IPM commenced in October 2022 where the project target in 2022 was met and a new Company Best Composite Time (BCT) at 4 days is achieved vs. conventional drilling. The project has strong In-Country Value (ICV) component by utilizing indigenous service providers and achieving the deployment of a 90% local workforce.
Renewables for Subsea Power – Transformational Low Carbon Subsea Power Project
Authors: Slorach P. , Crossland I. , Silva A. , Money N. 
Published: October 2023

Abstract
Momentum is building within the global offshore oil and gas industry to reduce carbon emissions in line with net zero targets and industry agreements around decarbonization such as the North Sea Transition Deal in the UK. As part of this drive to reduce emissions and to decrease reliance on traditional sources of power, integration of renewables within offshore operations is increasingly being seen as a viable solution.
In order to encourage wider adoption of renewables within these operations, successful projects must be demonstrated to show the viability of renewables in this environment, as well as the capability of overcoming the intermittency challenges associated with renewables.
The Renewables for Subsea Power (RSP) project, launched in 2020, is said to be a first-of-a-kind commercial scale demonstrator project which provides a fully integrated offshore power and over-the-horizon communications solution through the integration of a wave energy device (Mocean Energy) and a subsea battery energy storage system (Verlume). The project demonstrates power export to the subsea energy management system, powering both subsea controls equipment (Baker Hughes) and underwater vehicles (Transmark Subsea) through a remote wireless communication link to the subsea equipment.
In this paper, the focus will be on the development and progress within the RSP project since the previous paper SPE-210910-MS (Crossland et al., 2022). Discussion will include observations from Phase 2 onshore commissioning, as well as the offshore demonstration which began in February 2023 in the UK North Sea and has been operational over a four-month period.
Beyond innovation in the developed hardware, the project provides a case study of a wider industry collaborative approach, addressing the need to explore ways of achieving a net zero future and work towards enhanced energy security, including for offshore operations. The project is relevant to numerous remote power provision applications across the ever-growing Blue Economy.