bluuebunny/crossref_metadata_2025_split huggingface dataset:
An Innovative Fluid Approach to Reservoir Drilling and Sand Screen Deployment: When Reality Meets Design and the Lessons Learned
Authors: Webber Claire , Langford Marc 
Published: November 2018

Abstract
An engineered dual-purpose drilling and screen-running fluid was required to achieve optimum oil production with increased operational efficiency in a tight pressure window environment. The fluid needed to pose minimal formation damage risk while drilling and avoid completion damage through plugging of the standalone sand screen. This required a balance between bridging material content and particle size distribution (PSD), and a low fluid rheology to minimize the equivalent circulating density (ECD). The wide temperature profile and predicted restrictive narrow pressure margin in the well favored the use of a low ECD Non-Aqueous-Fluid (NAF). An organoclay-free NAF solution was selected. To reduce solids loading and ECD further, the fluid was designed with a brine phase that was high-density calcium bromide. Sized ground marble was selected to bridge the largest pore throats (42-μm) in the reservoir sand and still be screened quickly to avoid plugging of the 150-μm 6 5/8-in. standalone sand control production screens. Fluid optimization was achieved through rheology, stability, and formation-damage testing. The return permeability on cores/matched sandstone of &gt;97%, indicated minimal formation damage risk when drilling and after production flowback/solids removal. In the field, the reservoir was drilled without major issue (i.e. no differential sticking, no down-hole losses) and the fluid quickly reached production screen test (PST) specifications prior to running screens. The sand screens were installed without issues. Although the sand section was significantly shorter than planned, the production from ~160 ft of net pay when the well was initially flowed produced as expected. After subsequent tie-in to the host floating production storage and offloading (FPSO) unit and upon choke opening, a gradual drop in production was observed. An acid job was performed via a subsea vessel-based operation and the planned production target exceeded the original clean-up well productivity.
Advanced Real-Time Reservoir Characterization Utilizing Full Magnetic Resonance Data While Drilling: A Case Study from Abu Dhabi
Authors: Al-Zaabi Fatema , Amer Mohamed , Al-Jaberi Salem , Afzal Nusrat , Abdelbagi Mohamed , Deng Lichuan , Soliman Ahmed , Kieduppatum Piyanuch , Bhatt Pranjal , Fernandes Warren 
Published: November 2018

Abstract
Reservoir A is an Upper Jurassic reservoir in offshore Abu Dhabi, composing layers of dense anhydrite and porous mixed lithology of dolomite and limestone. Petrophysical study from multiple wells suggests that the rock quality within the reservoir has significant lateral and vertical variations that can result in different flow capacities. Consequently, it is crucial to identify the rock quality variations and the consequent flow capacity in horizontal wells to optimize development plan, ideally in real-time. However, these lateral and vertical variations are not visible from conventional porosity (density / neutron) logs, making identification of rock quality very challenging. This paper introduces an innovative magnetic resonance (NMR)-based real-time method of permeability prediction and rock typing.
Wireline logs including NMR were acquired in a pilot well, providing porosity and extensive T2-based information (permeability index, irreducible and movable fluid volume and porosity partition). Routine core analysis was also available to calibrate the NMR data, achieving a suitable correlation for NMR permeability index calibration in this field. Several rock types could be identified with the Windland R35 technique using porosity and calibrated permeability from NMR. This identification was then validated by rock types from cores. The application of knowledge gained from the study led to advanced reservoir characterization solely based on the NMR log. The process was applied to high-angle and horizontal (HAHZ) wells where the NMR full-spectrum log while drilling was available.
Several slanted wells were drilled with a fit-for-purpose logging-while-drilling (LWD) suite including NMR for geo-steering and formation evaluation. The real-time LWD NMR data helped trace a remarkable change of irreducible water level through certain layers, suggesting that the subzones of Reservoir A changed pore geometry and rock type laterally, resulting in variations of flow capacity and reservoir performance.
In one example, this method indicated unexpected good rock quality in one of these subzones considering the experience from offset well. Subsequently, the LWD formation-testing tool confirmed the result with mobility measurements, proving the NMR-based methodology was valid.
This process normally applies to memory data after drilling, playing a key role in designing completion strategy in a timely manner. The process is also available in real-time while drilling if full NMR data is transmitted to surface, serving as a safer logging-tool for identification of sub-zones with additional valuable information compared to regular porosity tools with chemical radioactive source.
A Workflow to Integrate Core and Image Logs in Order to Enhance the Characterization of Subsurface Facies on Carbonate Reservoirs, Offshore Abu Dhabi
Authors: BinAbadat Ebtesam , Bu-Hindi Hani , Lehmann Christoph , Kumar Atul , AL-Harbi Haifa , AL-Ali Ahmed , Al Katheeri Adel 
Published: November 2018

Abstract
In this study, core and log data were integrated to identify intervals which are rich in stromatoporoids in an Upper Jurassic carbonate reservoir of an offshore green field Abu Dhabi. The main objective of this study was to recognize and stromatoporoids floatstones/rudstones in core, and develop criteria and workflow to identify them in uncored wells using borehole images.
The following workflow was used during this study: i) Identification of the stromatoporoid feature in pilot wells with core and borehole images, ii) Investigate the properties and architecture of stromatoporoid bodies, iii) Integrate the same scale of core observations with borehole images and conventional log data (gamma ray, neutron porosity and bulk density logs) to identify stromatoporoid-rich layers, iv) Performing a blind test on a well by using the criteria developed from previous steps to identify "stromatoporoid accumulations" on a borehole image, and validate it with core observations.
In the reservoir under investgation, stromatoporoid floatstones/rudstones intervals were identified and recognized both on core and borehole image in the pilot wells. These distinct reservoir bodies of stromatoporoids commonly occur in upper part of the reservoir and can reach to a thickness of around 20ft. The distribution and thickness of stromatoporoid bodies as well as growth forms (massive versus branching) were recognized on core and borehole images. The accumulations varied between massive beds of containing large pieces of stromatoporoids and grainstone beds rich in stromatoporoid debris. The massive beds of stromatoporoid accumulations are well developed in the northern part of the field. These layers can enhance the reservoir quality because of their distinct vuggy porosity and permeability that can reach up to several hundred of milidarcies (mD). Therefore, it is important to capture stromatoporoid layers both vertically and laterally in the static and dynamic model. Integrating borehole image data with core data and developing a workflow to identify stromatoporoid intervals in uncored wells is crucial to our subsurface understanding and will help to understand reservoir performance.
Integration of image log data which is calibrated to core and log data proved to be critical in generating reservoir facies maps and correlations, which were integrated into a sequence stratigraphic framework as well. The results were used in the static model in distribution of high permeability layers related to the distribution of stromatoporoids.
Failure Predictive Analytics Using Data Mining: How to Predict Unforeseen Casing Failures?
Authors: Noshi C. I. , Noynaert S. F. , Schubert J. J. 
Published: November 2018

Abstract
Despite numerous studies in the subject matter, industry has yet to resolve casing failure issues. A more interdisciplinary approach is taken in this study integrating seventy-eight land based wells using a data - driven approach to predict the reasons behind casing failure. This study uses a statistical software in collaboration with Python Scikit-learn implementation to apply different Data Mining and Machine Learning algorithms on twenty-four different features on the twenty failed casing data sets. Descriptive analytics manifested in visual 8representations included Normal Distribution Charts and Heat Map. Principal component Analysis (PCA) was used for dimensionality reduction. Supervised and unsupervised approaches were selected respectively based on the response. The algorithms used in this study included Support Vector Machine (SVM), Boot strap, Random Forest, Naïve Bayes, XG Boost, and K-Means Clustering. Nine models were then compared against each other to determine the winner. Features contributing to casing failure were identified based on best algorithm performance.
Jacket Design to Accommodate Offshore Levelling
Authors: N Nagaraju , Kumar Chaithanya , Shirsat Priyanka , Varghese Nitin 
Published: November 2018

Abstract
Industry standard requires jacket to be levelled with in the installation tolerance without overstressing the piles and the jacket. It is noted that jacket levelling analysis is not normally performed at design stage and may not have an established acceptable design criteria as it is difficult to simulate the exact field conditions in an analysis model. In deeper waters where most of the jackets are battered, piles and jacket can get overstressed if an acceptable levelling tolerance across piles are not defined in the installation procedure. As the jacket and pile are not connected during installation phase, the restraint offered by the pile depends on the gap between the jacket leg and pile while pulling one corner of the jacket. Depending on the jacket level and the gaps at the mud level during piling, the self-weight of the jacket may not be completely supported by the mudmat as the piling progress. Soil strength mobilised at installation may be different from the full strength mobilized during operating conditions. This gives raise to many possible restraint scenarios to be simulated for analyses. Further these design simulations are complicated by the actual clearance at site and the stage of the levelling as the levelling can be done at any time during piling. Also, the actual force required to level the jacket are noted to be generally less than the one predicted by the analysis. This paper presents the methodology used to perform the jacket levelling analysis for a jacket with four legs, describes the procedure developed to monitor the levelling operation at site and documents the field measurements for a platform installed by McDermott.
Near Real Simulations with Wireline and Production Testing Surveys in the Oil and Gas Industry
Authors: Chinchayan Gustavo , Whabi Anoop , Mittal Tarsem 
Published: November 2018

Abstract
In this highly competitive industry, technology and perfection in service delivery makes an organization stand out from the rest. One of the key contributors to achieving the highest level of service delivery is equipping the workforce with the required procedures, knowledge, and skills. The blended learning approach must include sufficient classroom sessions. A well-designed hands-on training infrastructure emulates the field environment under the controlled conditions of a training center.
A training facility was designed with the objective to simulate as many challenges and scenarios encountered in field operations. The facility design enabled the field crew to understand and safely apply procedures to deliver services above customer’s expectations.
A project that included drilling four wells was incorporated in the near-real simulations. The facility was equipped with an overhead gantry to enable lifting operations and interventions as well as labs to survey the wells with e-line. An additional Testing and Production Services flow-loop facility equipped with conventional and recent-generation multiphase-measurement equipment can also interact with wells. Bringing several product lines together under one roof has the potential to optimize resources and to deliver packaged solutions to the customers. One such example is the collaboration of Wireline Services with Testing and Production Services.
The core objective of this facility was to design a downhole environment focused on the concepts of well integrity, well isolation, production logging, cased-hole and open hole evaluation. Initial simulations in the facility enabled understanding of cement evaluation with different cement slurry weights. These simulations also enabled evaluating casing integrity with different casing thicknesses and different internal and external casing anomalies, which led to appreciating the vertical resolution capabilities of downhole sensors. Furthermore, the simulations enabled cement evaluation through fiberglass pipe, or glass-reinforced plastic (GRP).
The created environment will facilitate witnessing the behavior of modern sensors to evaluate anomalies through adjacent casings. It will provide an environment to test pulse-neutron tools to evaluate and detect water fluid movement behind casing. It enables grasping the concept of electrical log correlation for perforating services with gamma ray, casing collar locator (CCL), or tubing-conveyed perforating (TCP) assemblies, and it instills confidence to place the assemblies at the correct depth in a well. It was also planned to provide visualization while running production logging sensors with different flow and volume rates of water, oil, and air in conjunction with the Testing and Production Services flow-loop capabilities.
Such a blended-learning approach that covers multiple product lines creates immense value.
Digital Twin Through the Life of a Field
Authors: Føllesdal Tjønn Are 
Published: November 2018

Abstract
The global energy industry is being radically transformed by increased access to data and digitalization of tools and processes. When data is harnessed effectively and then combined with engineering insight it has the ability to radically improve how energy assets are designed, operated and optimized from concept and front end design all the way through the life of the field to decommissioning.
Aker Solutions has developed a data platform and series of software applications which together form a digital twin capable of optimizing energy operations at a product, facility and field level integrating subsea and topside facilities.
The digital twin, conceived during the early concept phase (or retrofit to existing assets), draws together diverse data sources into an integrated format which can be managed and enriched as the asset progresses through its lifecycle. Software applications built on this platform include: Using knowledge-based and adaptable building blocks, our early phase software application accelerates the development of concepts with the ability to rapidly explore different options and adjust and optimize to different customer driven variablesDuring detailed design phase, software applications are used to drive engineering automation and ensure that safety is built inherently into the designSimulation software applications are used to test and evaluate complex installation operations in a virtual environment before any offshore operations take placeDigital twin can add significant value during operations and maintenance activities with performance and integrity data collated and visualized helping to make informed decisions to ensure production optimization and continuityAt a product level, Aker Solutions’ connected subsea equipment uses software applications and analytics to perform condition monitoring and enable predictive maintenance, maximizing production uptime
This digital thread allows data to seamlessly transition across asset phases enabling engineers, operators and asset managers to make informed and confident data-driven decisions; increasing efficiency, reducing cost and reducing risk.
A Robust Production Engineering Strategy for Extended Reach Well for Sustained Performance
Authors: Othman Alaa Amin , Ali Yasser , Sau Rajes , Al Kiyoumi Ahmed 
Published: November 2018

Abstract
One of the most giant offshore multi-reservoir oil fields in the world has been developed using vertical, deviated and short horizontal wells drilled off-shore from wellhead platform towers. Towards the concept of cost optimization, further redevelopment of the oil field was planned using extended-reach long horizontal wells with throws greater than 18,000 ft and measured depths greater than 25,000 ft with some wells exceeding 35,000 ft, from artificial built islands by reducing the number of wells required to drain the reservoir with improving recovery. In order to enable transition to such concept, new well design strategic concepts were required to come up with the robust well completion design (both upper and lower completions) that is expected to be fit-for-purpose for 30+ years – well life time. Lots of uncertainties and challenges are faced in order to get to the goal of understanding different reservoirs behaviors such as, for better reservoirs development relying on dynamic reservoir models combined with actual geological, petrophysical, seismic and production data. Each piece of information yielded a certain potential that led to a certain completion design based on available data and expectations.
This paper will discuss the upper and lower completion designs, execution and performance from production engineering perspective to maximize productivity for the whole life cycle of this long horizontal wells. The extended lateral length in these wells warrants innovative designs in upper and lower completions as traditional completion designs no longer valid in addressing the challenges in these wells. The key well design and planning process involves designing the upper completion – tubing, gas lift system, downhole gauge and lower completion liner – Pre-perforated liner (PPL), Limited-entry Liner (LEL) or Inflow Control Devices (ICD) with annular isolation with packers, efficient initial start-up and clean up strategy, regular monitoring well performance and surveillance (e.g. downhole pressure monitoring, PLTs, fluid sample analysis etc.). The paper will also address the challenges in long horizontal wells such as accessibility, production/injection conformance and effective stimulation of the laterals.
Risk-Adjusted Underwater Inspection Intervals for Steel Piled Jackets
Authors: Foltz Raymond , Younan Adel 
Published: November 2018

Abstract
Inspection intervals have been long established in some jurisdictions around the world based on an assessment of acceptable risk from experience, judgment, and observations of past damage. In areas that do not have the benefit of decades of experience, the designated inspection intervals may be inheriting intervals from another region of the world, and in doing so, potentially subscribing to inspection interval frequencies that assume less or more risk than has been deemed acceptable in other areas of the world. This study investigates two prototype steel piled jacket platforms subjected to metocean conditions present in several areas of offshore development around the world, with the objective to investigate the relative fatigue performance of the prototype structures in these varied environments. The relative performance of these various locations may lend insight into the implementation of risk-consistent inspection intervals for structural integrity maintenance programs.
Nearbalanced Nitrified Foam Drilling: A New Frontier for the Drilling of Depleted & Fractured Carbonates - A Study on the Design, Execution, and Results on Multiple Wells
Authors: Khalid Ali , Ashraf Qasim , Luqman Khurram , Moussa Ayoub Hadji , Nabi Agha Ghulam , Baig Umair , Mahmood Amer 
Published: November 2018

Abstract
Carbonate platforms are one of the most common reservoirs on earth, and as such are one of the most frequently explored.
Sulaiman fold belt in Pakistan is known to contain multiple hydrocarbon bearing carbonate formations. One such formation is the Sui Main Limestone formation. The formation when first discovered was known to contain over 9.5 Tcf of gas in Sui field, and up to 5.0 Tcf of gas in the neighboring Zin field. Over the years due to extensive field development and production, the Sui Main Limestone reservoir has been driven to depletion. Operators are now looking to explore deeper horizons in the same fields.
The challenge in deeper exploration of the subject fields is now a depleted pressure of about 2.1 ppg EMW of the Sui Main Limestone formation. In addition to the low pressure, the SML formation is highly fractured in nature. These two factors resulted in massive circulation losses when an attempt to drill a well was made through the approximately 650 m width of the SML formation. To cure losses, operators resorted to heavy LCM pills, and numerous cement plugs. Losses in the hydrocarbon bearing SML formation also led to well control and stuck pipe events on multiple occasions. Successful drilling through the whole width of SML formation would sometimes take up to almost 3 months. Drilling time and lost circulation materials thus generated excessive well costs.
The operator sought a solution which would eliminate circulation losses in the SML formation, and cut down drilling time substantially. An underbalanced system was first considered for achieving these objectives but as the SML formation bore sour gas and excessive equipment would be required for a safe underbalanced operation, the option was ruled out. A nearbalanced nitrified foam system was thus designed to be able to drill the SML formation delivering the same benefits of an underbalanced operation without its perils.
By applying a nearbalanced nitrified drilling technique, operators in the subject fields were able to cut down the drilling time to about 3-5 days, achieve a substantial increase in drilling performance, and practically reduce the NPT to 0.
This paper studies the planning & design of a nearbalanced nitrified foam system for two different wells with hole sections of size 17", and 8-1/2". The paper also discusses the equipment selection, the wellsite execution, and the results achieved by applying nearbalanced nitrified foam drilling in the subject fields.